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40.1031 40.1099 35.039 35.130 40.0250 40.0624 40.0896 40.1032 40.1100 24 40.0523 40.1645 40.0659 40.1781 40.0795 40.1917 14.79 25 14.80 40.0524 40.1646 40.0660 40.1782 40.0796 40.1918 26 19.57 14.81 36 40.0525 40.1647 40.0661 40.1783 40.0797 40.1919 14.82 37 14.83 40.0526 40.1648 40.0662 40.1784 40.0798 40.1920 38 14.84 40.0527 40.1649 40.0663 40.1785 40.0799 40.1921 40.1882 14.85 5 40.0972 40.0528 40.1650 40.0664 40.1786 40.0800 40.1922 40.0529 40.1651 40.0665 40.1787 40.0801 40.1923 15 40.0530 40.1652 40.0666 40.1788 40.0802 40.1924 6 17 40.0531 40.1653 40.0667 40.1789 40.0803 40.1925 18 7 40.0532 40.1654 40.0668 40.1790 40.0804 40.1926 7.01 21 7.02 22 40.0533 40.1655 16 40.0669 40.1791 40.0805 40.1927 7.03 17 27 40.0534 40.1656 40.0670 40.1792 40.0806 40.1928 7.04 18 17 28 19.60 7.05 1 40.0535 40.1657 19 40.0671 40.1793 40.0807 40.1929 29 2 7.06 20 30 3 40.0536 40.1658 40.0672 40.1794 40.0808 40.1930 7.07 31 4 7.08 40.0537 40.1659 40.0673 40.1795 40.0809 40.1931 32 7.09 5 33 40.0538 40.1660 40.0674 40.1796 40.0810 40.1932 7.10 false 6 7.11 40.0539 40.1661 40.0675 40.1797 40.0811 40.1933 7.12 7 40.1662 40.0540 40.0676 40.1798 40.0812 40.1934 7.13 8 7.14 40.0541 40.1663 40.0677 40.1799 40.0813 40.1935 7.15 9 40.0542 40.1664 40.0678 40.1800 40.0814 40.1936 7.16 10 7.17 40.0543 40.1665 40.0679 40.1801 40.0815 40.1937 7.18 11 40.0544 40.1666 40.0680 40.1802 40.0816 40.1938 7.19 8 12 7.20 19.63 42 40.0545 40.1667 40.0681 40.1803 40.0817 40.1939<span style="color:#000000;font-family:'Arial',sans-serif;font-size:9pt;font-weight:400;line-height:120%">12. See pages 122 through 123.</span>7.21 13 40.0546 40.1668 40.0682 40.1804 40.0818 40.1940 7.22 14 7.23 40.0547 40.1669 40.0683 40.1805 40.0819 40.1941 7.24 15 40.0548 40.1670 40.0684 40.1806 40.0820 40.1942 7.25 16 7.26 Copies Submitted 40.1169 40.0549 40.1671 40.0685 40.1807 40.0821 40.1943 7.27 17 51.1 40.0550 40.1672 40.0686 40.1808 40.0822 40.1944 7.28 C001553 18 7.29 40.0551 40.1673 40.0687 40.1809 40.0823 40.1945 7.30 19 40.0552 40.1674 40.0688 40.1810 40.0824 40.1946 7.31 20 7.32 40.0553 40.1675 40.0689 40.1811 40.0825 40.1947 7.33 21 40.1170 40.0554 40.1676 40.0690 40.1812 40.0826 40.1948 7.34 22 7.35 19.66 40.0555 40.1677 40.0691 40.1813 40.0827 40.1949 7 O 52 7.36 23 8 40.0556 40.1678 40.0692 40.1814 40.0828 40.1950 7.37 9 7.38 40.0455 40.0251 40.1373 40.0319 40.1441 40.0387 40.1509 40.1713 40.0727 40.1849 42.17 5 19.22 40.0456 40.0252 40.1374 40.0320 40.1442 40.0388 40.1510 40.1714 40.0728 40.1850 19.23 40.0082 42.19 40.1171 7 40.0457 40.0253 40.1375 40.0321 40.1443 40.0389 40.1511 40.1715 40.0729 40.1851 42.20 19.25 8 40.0458 40.0254 40.1376 40.0322 40.1444 40.0390 40.1512 40.1716 40.0730 40.1852 19.26 19 9 42.22 18 40.0459 40.0255 40.1377 40.0323 40.1445 40.0391 40.1513 40.1717 40.0731 40.1853 42.23 10 20 19.28 40.0460 40.0256 40.1378 40.0324 40.1446 40.0392 40.1514 40.1718 40.0732 40.1854 19.29 11 42.25 12 40.0461 40.0257 40.1379 40.0325 40.1447 40.0393 40.1515 40.1719 40.0733 40.1855 42.26 40.0083 14 19.31 40.1172 40.0258 40.1380 40.0326 40.1448 40.0394 40.1516 40.0462 40.1720 40.0734 40.1856 16 19.32 42.28 18 40.0259 40.1381 40.0327 40.1449 40.0395 40.1517 40.0463 40.1721 40.0735 40.1857 42.29 20 19.34 40.0260 40.1382 40.0328 40.1450 40.0396 40.1518 40.0464 40.1722 40.0736 40.1858 21 19.35 22 40.0465 40.0261 40.1383 40.0329 40.1451 40.0397 40.1519 40.1723 40.0737 40.1859 23 19.37 40.0262 40.1384 40.0330 40.1452 40.0398 214651101 40.1520 40.0466 40.1724 40.0738 24 19.38 25 40.1173 40.0467 40.0263 40.1385 40.0331 40.1453 40.0399 40.1521 40.1725 40.0739 40.1861 4228165 26 19.40 40.0468 40.0264 40.1386 32005402 40.0332 40.1454 40.0400 40.1522 40.1726 40.0740 27 19.41 28 40.0265 40.1387 40.0333 40.1455 40.0401 40.1523 40.0469 40.1727 40.0741 40.1863 29 19.43 40.0470 40.0266 40.1388 40.0334 40.1456 40.0402 40.1524 40.1728 40.0742 40.1864 30 19.44 31 40.0471 40.0267 40.1389 40.0335 40.1457 40.0403 40.1525 40.1729 40.0743 40.1865 38 40.0085 32 19.46 40.1174 40.0268 40.1390 40.0336 40.1458 40.0404 40.1526 53 40.0472 40.1730 40.0744 33 19.47 34 40.1527 40.0473 40.0269 40.1391 40.0337 40.1459 40.0405 40.1731 40.0745 40.1867 35 19.49 40.0474 40.0270 40.1392 40.0338 40.1460 40.0406 40.1528 40.1732 40.0746 40.1868 36 19.50 37 40.0475 40.0271 40.1393 40.0339 40.1461 40.0407 40.1529 40.1733 40.0747 40.1869 65 38 30 19.52 64 40.0476 40.0272 40.1394 40.0340 40.1462 40.0408 40.1530 40.1734 40.0748 40.1870 39 1 19.53 31 2 40 40.1175 40.0477 40.0273 40.1395 32 40.0341 40.1463 40.0409 40.1531 40.1735 40.0749 3 41 19.55 35 40.0478 40.0274 40.1396 40.0342 40.1464 40.0410 40.1532 67 40.1736 40.0750 42 19.56 40.0850 43 40.0275 40.1397 40.0343 40.1465 40.0411 40.1533 68 40.0479 40.1737 40.0751 44 19.58 40.1534 40.0276 40.1398 40.0344 40.1466 40.0412 40.0480 40.1738 40.0752 40.1874 45 19.59 46 40.0481 40.0277 40.1399 40.0345 40.1467 9.11 40.0413 40.1535 40.1739 40.0753 40.0087 47 19.61 40.1176 40.0482 40.0278 40.1400 9.1 40.0346 40.1468 40.0414 40.1536 40.1740 40.0754 48 19.62 9.12 49 40.0483 40.0279 40.1401 40.0347 40.1469 40.0415 40.1537 40.1741 40.0755 40.1877 77 9.13 50 76 19.64 40.0484 40.0280 40.1402 40.0348 40.1470 9.14 40.0416 40.1538 40.1742 40.0756 50.1 19.65 9.15 40.0485 40.0281 40.1403 40.0349 40.1471 40.0417 40.1539 40.1743 40.0757 40.1879 9.16 true 19.67 40.0984 40.0486 40.0282 40.1404 40.0350 40.1472 9.17 40.0418 40.1540 40.1744 40.0758 19.68 40.1191 9.18 40.0487 40.0283 40.1405 40.0351 40.1473 40.0419 40.1541 40.1745 40.0759 40.1881 9.19 1 40.0488 40.0284 40.1406 40.0352 40.1474 9.2 40.0420 40.1542 40.1746 40.0760 2 C001553 1618 SOUTH GAINESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 EAST WATKINSVILLE 230, , , 0 2023-01-01 2023-12-31 C001553 1070 MCDONOUGH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1398 PRESIDENT STREET SEWAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 223 BRONWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1058 MARTIN MARIETTA (Junction City), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1726 TALMO TAP PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 62 ARCHER DANIELS MIDLAND (Valdosta), Distribution, Unattended 2023-12-31 C001553 1181 MULKEY ROAD, Distribution, Unattended 2023-12-31 C001553 103 BAKER PLACE, Distribution, Unattended 2023-12-31 C001553 342 COATS AMERICAN (Toccoa), Distribution, Unattended 2023-01-01 2023-12-31 C001553 235 BUCKHEAD PRIMARY, Distribution, Unattended 2023-12-31 C001553 FIFTEENTH STREET 042568, VERDERY STREET 115 KV, SSP, Overground 2023-01-01 2023-12-31 C001553 Plant McDonough - Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:NuclearProductionPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1885 VULCAN MATERIALS (Grayson), Distribution, Unattended 2023-12-31 C001553 1255 NUTRASWEET, Distribution, Unattended 2023-12-31 C001553 485 DIVIDEND ROAD, Distribution, Unattended 2023-12-31 C001553 1543 SCHERER FGD 3/4, Generation, Attended 2023-12-31 C001553 668 FRUIT OF THE LOOM (Dillard), Distribution, Unattended 2023-01-01 2023-12-31 C001553 365 COLONIAL PIPELINE (Bremen), Distribution, Unattended 2023-01-01 2023-12-31 C001553 2023-01-01 2023-09-30 C001553 322 CHOKEE PLANTATION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 EAST COLUMBUS 230 KV, , , 26020 2023-01-01 2023-12-31 C001553 79 ATLANTA FULTON COUNTY WATER TREATMENT, Distribution, Unattended 2023-12-31 C001553 1961 WHITESBURG, Distribution, Unattended 2023-12-31 C001553 1623 SOUTH MADISON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 389 CONLEY CREEK, Distribution, Unattended 2023-12-31 C001553 191 BOULEVARD (Savannah), Transmission, Unattended 2023-01-01 2023-12-31 C001553 PJM Interconnection, OS, 2023-01-01 2023-12-31 C001553 915 JUNCTION CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1119 MILLEDGEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 818 HAZLEHURST WOOD PELLETS, Distribution, Unattended 2023-12-31 C001553 362 COLONELS ISLAND, Distribution, Unattended 2023-12-31 C001553 1343 PETTIT CREEK, Distribution, Unattended 2023-12-31 C001553 1744 TEXAS VALLEY, Distribution, Unattended 2023-12-31 C001553 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember ferc:ElectricPlantInServiceMember 2023-01-01 2023-12-31 C001553 WADLEY VIDALIA #1 230 KV LN, 230, 46.16, 252047 2023-01-01 2023-12-31 C001553 946 KING STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 129 BEAVER DRIVE, Distribution, Unattended 2023-12-31 C001553 225 BROOKHAVEN BOULEVARD, Distribution, Unattended 2023-12-31 C001553 1169 MOUNT VERNON MILLS (Alto), Distribution, Unattended 2023-12-31 C001553 983 LEWIS DRIVE, Distribution, Unattended 2023-12-31 C001553 552 EATONTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 734 GOLDEN PEANUT (Dawson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1138 MISSION POND, Distribution, Attended 2023-01-01 2023-12-31 C001553 942 KINCHAFOONEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 999 LITHONIA, Distribution, Unattended 2023-12-31 C001553 1263 OAKFIELD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1368 PLEASANTDALE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 902 JESUP CITY, Distribution, Unattended 2023-12-31 C001553 1703 SUPER SOD FARM PM, Distribution, Unattended 2023-12-31 C001553 1084 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1581 SIMPSON LUMBER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 660 FOWLER STREET, Distribution, Unattended 2023-12-31 C001553 1619 SOUTH GEORGETOWN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1646 SOUTHERN MILLS (Zebulon), Distribution, Unattended 2023-12-31 C001553 1036 MAGNOLIA MANOR, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricOtherFacilitiesMember Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 301 CERTAINTEED (Social Circle), Distribution, Unattended 2023-12-31 C001553 921 KAMIN MINE (Thomson), Distribution, Unattended 2023-12-31 C001553 439 DALTON, Distribution, Unattended 2023-12-31 C001553 1969 WILLINGHAM DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Bartow 2nd Series 2022 - Variable 2023-01-01 2023-12-31 C001553 1007 LLOYD SHOALS HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 1938 WEST CRAWFORDVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 620 FLAT ROCK ROAD, Distribution, Unattended 2023-12-31 C001553 10 AINSLIE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 282 CASCADE HEIGHTS, Distribution, Unattended 2023-12-31 C001553 Unassigned ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 394 COOLIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 531 EAST BEACH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1055 MARTIN MARIETTA (Camak), Distribution, Unattended 2023-12-31 C001553 Motor Vehicle Tag Fees, Other Taxes and Fees, 0, 2022-12-31 C001553 2007 WRIGHTSBORO ROAD, Distribution, Unattended 2023-12-31 C001553 MCDONOUGH NO. 3 OIl 2023-01-01 2023-12-31 C001553 1778 TOLLESON LUMBER (Perry), Distribution, Unattended 2023-01-01 2023-12-31 C001553 841 HON, Distribution, Unattended 2023-12-31 C001553 1076 MCINTOSH CC, Generation, Attended 2023-01-01 2023-12-31 C001553 FICA-COVID 19 Federal, Payroll Tax, 0, 2023-01-01 2023-12-31 C001553 2021 YOSHIDA, Distribution, Unattended 2023-12-31 C001553 1105 MELDRIM, Transmission, Unattended 2023-01-01 2023-12-31 C001553 BOWEN Oil 2023-01-01 2023-12-31 C001553 951 KIOKEE ROAD, Distribution, Unattended 2023-12-31 C001553 882 JACK MCDONOUGH CC #4, Generation, Attended 2023-12-31 C001553 279 CARROLLTON, Transmission, Unattended 2023-12-31 C001553 498 DODGE AGRICULTURAL PARK PM, Distribution, Unattended 2023-12-31 C001553 1792 TRENTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 365 2023-01-01 2023-12-31 C001553 1641 SOUTHERN GATEWAY, Distribution, Unattended 2023-12-31 C001553 1735 TEMPERANCE PM, Distribution, Unattended 2023-12-31 C001553 2020 YONAH, Generation, Attended 2023-01-01 2023-12-31 C001553 1470 RINGGOLD, Distribution, Unattended 2023-12-31 C001553 NextEra Solar, OS, 2023-01-01 2023-12-31 C001553 1485 ROBERTS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NitrogenOxideMember 2023-12-31 C001553 341 COAL MOUNTAIN, Distribution, Unattended 2023-12-31 C001553 ferc:FranchiseTaxMember 2023-01-01 2023-12-31 C001553 Boyd Ave Substation Site 2023-01-01 2023-12-31 C001553 DEMAND SIDE MANAGEMENT CERTIFICATION - DOCKET NOS. 42311, 43040, and 44161 2023-01-01 2023-12-31 C001553 710 GEORGIA PORTS AUTHORITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2005 WRENS PRIMARY, Distribution, Unattended 2023-12-31 C001553 1524 SAINT SIMONS, Distribution, Unattended 2023-12-31 C001553 State Income Tax, Income Tax, Georgia, 2023-12-31 C001553 629 FLORIDA ROCK (Griffin), Distribution, Unattended 2023-12-31 C001553 1290 OWENS BROCKWAY (Sylvan Road), Distribution, Unattended 2023-12-31 C001553 371 COLONIAL PIPELINE (Smyrna), Distribution, Unattended 2023-01-01 2023-12-31 C001553 706 GEORGIA PACIFIC (Warrenton), Distribution, Unattended 2023-12-31 C001553 1606 SOUTH ADEL, Distribution, Unattended 2023-12-31 C001553 Cooperative Energy South Mississippi Electric Power Association South Mississippi Electric Power Association FNO N/A 641 2023-01-01 2023-12-31 C001553 952 KIRKHILL MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 613 FIFTY SECOND STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1819 TYCO PLASTICS #11 PD, Distribution, Unattended 2023-12-31 C001553 1652 SOUTHERN STATES CO-OP, Distribution, Unattended 2023-12-31 C001553 Sales Commissions (d) 2023-12-31 C001553 558 EDISON, Distribution, Unattended 2023-12-31 C001553 ROW Services Perfection ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1344 PHARMATECH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1702 SUNSHINE BISCUIT (Columbus), Distribution, Unattended 2023-12-31 C001553 Customer Service System (CSS) Upgrades 2023-01-01 2023-12-31 C001553 390 CONSOLIDATED MINERALS PD, Distribution, Unattended 2023-12-31 C001553 911 JOHNSON FERRY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 253 BUTLER, Distribution, Unattended 2023-12-31 C001553 1794 TREUTLEN, Distribution, Unattended 2023-12-31 C001553 1548 SCHERER UNIT 1, Generation, Attended 2023-01-01 2023-12-31 C001553 641 FORREST ROAD (Macon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2017A - 5.00% 2023-01-01 2023-12-31 C001553 Advanced Contribution for 2023-01-01 2023-12-31 C001553 1152 MONTEZUMA, Distribution, Unattended 2023-12-31 C001553 Gas and Electric Hedges 2023-01-01 2023-12-31 C001553 Substation Reliability Improvements 2023-01-01 2023-12-31 C001553 Credit Line Fees (b) 2023-01-01 2023-12-31 C001553 BOULEVARD, BUCKHEAD, Steel Pole, 1351 SSAC 2023-01-01 2023-12-31 C001553 185 BONANZA, Distribution, Unattended 2023-12-31 C001553 599 FAYETTEVILLE ROAD, Distribution, Unattended 2023-12-31 C001553 Protective Relay Modernization Project 2023-01-01 2023-12-31 C001553 934 KEYSTONE MEMORIALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1967 WILLACOOCHEE CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1090 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1135 MILLIRONS ROAD, Distribution, Unattended 2023-12-31 C001553 1602 SOLO CUP #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 4-6 Oil 2023-01-01 2023-12-31 C001553 1438 RAY MOUNTAIN 2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 143 BERKELEY LAKE, Distribution, Unattended 2023-12-31 C001553 307 CHAUNCEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1014 LOOKOUT VALLEY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 977 LAST LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 5 ACWORTH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 592 FACTORY SHOALS ROAD, Distribution, Unattended 2023-12-31 C001553 Revenue Erosion 2023-12-31 C001553 1666 SPRING STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 15 AIRPORT ROAD, Distribution, Unattended 2023-12-31 C001553 1762 THOMSON AREA #8 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 989 LIMESTONE CREEK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1157 MORGAN FALLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1595 SOCIAL CIRCLE, Distribution, Unattended 2023-12-31 C001553 Storm Assistance, Mississippi Power Company 2023-01-01 2023-12-31 C001553 980 LEE HARRIS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 340 CLYATTVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1889 VULCAN MATERIALS (Norcross), Distribution, Unattended 2023-12-31 C001553 1559 SCOTTDALE, Distribution, Unattended 2023-12-31 C001553 Capital Contributions from Parent Company 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Georgia, 2023-12-31 C001553 1138 MISSION POND, Distribution, Attended 2023-12-31 C001553 Deferred Compensation 2023-01-01 2023-12-31 C001553 820 HERCULES (Covington), Distribution, Unattended 2023-12-31 C001553 1377 PORTERDALE PRIMARY, Distribution, Unattended 2023-12-31 C001553 Premium on Reacquired Debt ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 272 CANTON #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1028 MACON COUNTY PRISON #1 PD (South), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1523 SAINT SIMONS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 348 COBB MARIETTA WATER (Allatoona), Distribution, Unattended 2023-12-31 C001553 1440 RAYONIER (Jesup), Distribution, Unattended 2023-12-31 C001553 631 FLOWERY BRANCH, Distribution, Unattended 2023-12-31 C001553 Langdale - Retired (D) 2023-12-31 C001553 Software Licensing 2023-01-01 2023-12-31 C001553 467 DEKALB VOCATIONAL SCHOOL, Distribution, Unattended 2023-12-31 C001553 WEST FRASER & STANDARD CONCRETE PETIT - DOCKET NOS. 43689, 43690, and 43688 2023-12-31 C001553 125 BAYER CROPSCIENCE, Distribution, Unattended 2023-12-31 C001553 389 CONLEY CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 94 AUSTELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1199 NORDIC COLD STORAGE #2 (Doraville), Distribution, Unattended 2023-12-31 C001553 1958 WHITEMARSH ISLAND, Distribution, Unattended 2023-12-31 C001553 1129 MILLIKEN (Lagrange), Distribution, Unattended 2023-01-01 2023-12-31 C001553 194 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1538 SAVANNAH FOODS, Distribution, Unattended 2023-12-31 C001553 431 CURRAHEE HEIGHTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Mcintosh - Outage Projects 2023-01-01 2023-12-31 C001553 250 BURNT HICKORY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 311 CHEROKEE ROAD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 591 FACTORY SHOALS ROAD, Distribution, Unattended 2023-12-31 C001553 451 DAWSON FOREST, Distribution, Unattended 2023-12-31 C001553 502 DONNA WAY PM, Distribution, Unattended 2023-12-31 C001553 1751 THIELE KAOLIN (Limestone Creek), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1410 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 594 FAIR ROAD, Distribution, Unattended 2023-12-31 C001553 ferc:NonUtilityMember Other Income and Deductions 2023-12-31 C001553 1979 WILSON, Generation, Attended 2023-12-31 C001553 WABASH-BOULEVARD 230 KV LN, 230, 3.69, 772 2023-01-01 2023-12-31 C001553 SASND-C Seasonal Agricultural Service - Non-Demand 2023-01-01 2023-12-31 C001553 1527 SANDERSON FARMS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 962 LAKE LANIER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1321 PCS NITROGEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1838 UNIVERSITY CENTER, Distribution, Unattended 2023-12-31 C001553 330 CLARKSTON, Distribution, Unattended 2023-12-31 C001553 1584 SIX MILE, Distribution, Unattended 2023-12-31 C001553 2413, WALLACE DAM 2023-12-31 C001553 842 HONDA, Distribution, Unattended 2023-12-31 C001553 Lewiston Road Substation Site 2023-01-01 2023-12-31 C001553 883 JACK MCDONOUGH CC #4, Generation, Attended 2023-12-31 C001553 Hydraulic 2023-01-01 2023-12-31 C001553 VOGTLE BUS #2 , VOGTLE 3&4 BUS #4, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 1488 ROBINS AFB #2, Distribution, Unattended 2023-12-31 C001553 993 LINWOOD WRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 544 EAST VIDALIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 121 BATTLECREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1911 WARM SPRINGS ROAD, Distribution, Unattended 2023-12-31 C001553 Double Run Solar, OS, 2023-01-01 2023-12-31 C001553 Federal Tax Credits 2023-01-01 2023-12-31 C001553 677 GAINESVILLE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 815 HAWTHORNE, Distribution, Unattended 2023-12-31 C001553 1417 PROPEX #7 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Mississippi, 2022-12-31 C001553 2017 YATES COMMON, Transmission, Unattended 2023-12-31 C001553 1143 MOHAWK INDUSTRIES (Lyerly), Distribution, Unattended 2023-12-31 C001553 DOE Loan 1.652% - 2044 2023-12-31 C001553 93 AUSTELL, Distribution, Unattended 2023-12-31 C001553 Gas and Electric Hedges 2023-12-31 C001553 Contract Retention 2023-01-01 2023-12-31 C001553 568 ELLIJAY PRIMARY, Transmission, Unattended 2023-12-31 C001553 766 GRESHAMVILLE PM (RETIRED), Distribution, Unattended 2023-12-31 C001553 1440 RAYONIER (Jesup), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1175 MOUNTAIN VIEW, Distribution, Unattended 2023-12-31 C001553 Plant Scherer - Water ferc:ElectricUtilityMember 2023-12-31 C001553 796 HARTFORD PM, Distribution, Unattended 2023-12-31 C001553 Georgia Power Company Rate ScheduleFERC No. 833, ER99-3051-000 2023-01-01 2023-12-31 C001553 0 ferc:ElectricUtilityMember 2022-12-31 C001553 629 FLORIDA ROCK (Griffin), Distribution, Unattended 2023-01-01 2023-12-31 C001553 See Attachment 261.1 2023-01-01 2023-12-31 C001553 1172 MOUNT ZION, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1301 PACTIV #3 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1322 PEACH ORCHARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1865 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 1305 PALM STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Hobnail Solar, LLC, LU, 2023-01-01 2023-12-31 C001553 249 BURKHALTER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1390 POWERS FERRY, Distribution, Unattended 2023-12-31 C001553 58 AQUILLA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 391 CONTAINER CORPORATION OF AMERICA, Distribution, Unattended 2023-12-31 C001553 102 BAKER PLACE, Distribution, Unattended 2023-12-31 C001553 1063 MARVIN GRIFFIN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Oglethorpe Power Corporation, LU, 2023-01-01 2023-12-31 C001553 512 DRURY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1269 OGLETHORPE MALL, Distribution, Unattended 2023-12-31 C001553 1494 ROBINS CT, Generation, Attended 2023-12-31 C001553 410 COUNTY FARM ROAD, Distribution, Unattended 2023-12-31 C001553 186 BONE PM, Distribution, Unattended 2023-12-31 C001553 943 KING AMERICA, Distribution, Unattended 2023-12-31 C001553 1825 U.S. MARINE CORPS (MOCK ROAD), Distribution, Unattended 2023-12-31 C001553 300 CERTAINTEED (Social Circle), Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE-WADLEY 230 KV LN, 230, 47.96, 498135 2023-01-01 2023-12-31 C001553 35 ALLEN ROAD, Distribution, Unattended 2023-12-31 C001553 1132 MILLIKEN (New Holland) Gainesville, Distribution, Unattended 2023-01-01 2023-12-31 C001553 395 COOPER BRIDGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2022A - 4.70% 2023-12-31 C001553 1984 WINCHESTER SUBDIVISION PM, Distribution, Unattended 2023-12-31 C001553 ferc:IncomeTaxMember 2023-12-31 C001553 1654 SOUTHERN WOOD SUPPLIES, Distribution, Unattended 2023-12-31 C001553 RTPHSLM Real Time Pricing Hour Ahead - School Load Management 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 4-6 2023-01-01 2023-12-31 C001553 DOE Loan 3.213% - 2044 2023-01-01 2023-12-31 C001553 528 EAST AUGUSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1108 MERIWETHER PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:SulfurDioxideMember Purchases/Transfers: 2023-01-01 2023-12-31 C001553 a. Overhead, Power Delivery Transmission Research 2023-01-01 2023-12-31 C001553 790 HAPEVILLE, Distribution, Unattended 2023-12-31 C001553 27 ALADDIN MILLS (Forsyth), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1827 U.S. MARINE CORPS SUPPLY DEPOT, Distribution, Unattended 2023-12-31 C001553 1495 ROCHELLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:DistributionSubstationMember 2023-12-31 C001553 141 BERCKMAN ROAD, Distribution, Unattended 2023-12-31 C001553 1916 WARRENTON AREA #5 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1619 SOUTH GEORGETOWN PM, Distribution, Unattended 2023-12-31 C001553 1435 RALSTON PURINA MILLS (Gainesville), Distribution, Unattended 2023-12-31 C001553 810 HATCH, Generation, Attended 2023-12-31 C001553 1161 MORGANVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCGRAU FORD , MOSTELLER SPRINGS, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 Outage 2023-01-01 2023-12-31 C001553 1009 LOCKEBY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Vogtle 1&2 - Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1687 STOCKBRIDGE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1739 TENNECO AUTOMOTIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 523 DURHAM PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 System Operations - Study Driven - Generation Changes 2023-01-01 2023-12-31 C001553 1253 NORTHWINDS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1533 SARDIS, Distribution, Unattended 2023-12-31 C001553 1490 ROBINS AFB #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 928 KENNESAW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 151 BIG CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1805 TRUMAN PARKWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1756 THIELE KAOLIN (Wrens), Distribution, Unattended 2023-12-31 C001553 1277 OLD NATIONAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1517 RUCKER BROTHERS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 0 ferc:ElectricUtilityMember 2023-12-31 C001553 1385 POWDER SPRINGS, Distribution, Unattended 2023-12-31 C001553 Common Stock (No Par) 2023-12-31 C001553 1062 MARVIN GRIFFIN ROAD, Distribution, Unattended 2023-12-31 C001553 1326 PEACHTREE, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Mississippi, 2023-01-01 2023-12-31 C001553 939 KIMBALL BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1551 SCHERER UNIT 3, Generation, Attended 2023-12-31 C001553 Asset Retirement Obligations 2022-12-31 C001553 307 CHAUNCEY, Distribution, Unattended 2023-12-31 C001553 1419 PUBLIC SAFETY TRAINING CENTER, Distribution, Unattended 2023-12-31 C001553 1852 VICTORY DRIVE, Distribution, Unattended 2023-12-31 C001553 791 HARD LABOR CREEK ESTATES PM, Distribution, Unattended 2023-12-31 C001553 472 DEMOREST, Distribution, Unattended 2023-12-31 C001553 Southern Electric Generating Co.ferc:EquityContributionMember 2023-12-31 C001553 STATESBORO 230 KV (SAV), 230, 15.73, 0 2023-01-01 2023-12-31 C001553 1637 SOUTHEAST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , Research Administration 588 2023-01-01 2023-12-31 C001553 Southern Company Services, OS, 2023-01-01 2023-12-31 C001553 1908 WANSLEY FGD, Generation, Attended 2023-12-31 C001553 917 JUNCTION CITY MINING #3 PD, Distribution, Unattended 2023-12-31 C001553 521 DUNCAN MILL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1185 NACOOCHEE, Generation, Attended 2023-12-31 C001553 1709 SWAINSBORO AREA #5 PM, Distribution, Unattended 2023-12-31 C001553 1420 PULASKI, Distribution, Unattended 2023-12-31 C001553 552 EATONTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 7% 2023-01-01 2023-12-31 C001553 364 2023-01-01 2023-12-31 C001553 265 CAMP JOSEY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 456 DEAN FOREST, Transmission, Unattended 2023-01-01 2023-12-31 C001553 285 CASTLEBERRY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Facility ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1571 SHAW INDUSTRIES (Milledgeville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1857 VIENNA PRIMARY, Transmission, Unattended 2023-12-31 C001553 1284 OPHELIA SMITH PM, Distribution, Unattended 2023-12-31 C001553 FLA ST LN 230 KV LN, 230, 32.84, 470277 2023-01-01 2023-12-31 C001553 2013 YATES 6&7, Generation, Attended 2023-12-31 C001553 TALBOT COUNTY 230 KV (SONAT, 230, 1.87, 223372 2023-01-01 2023-12-31 C001553 4%ferc:ElectricUtilityMember 2023-12-31 C001553 Michael K. Anderson 2023-01-01 2023-12-31 C001553 NextEra Gulf, OS, RS-138 2023-01-01 2023-12-31 C001553 Morgan Stanley Capital Group, Inc., OS, 2023-01-01 2023-12-31 C001553 ferc:OtherTaxesAndFeesMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Other General Plant ferc:ElectricUtilityMember 2023-12-31 C001553 Federal Income Taxes 2023, Income Tax, ,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1258 OAK GROVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:FranchiseTaxMember 2023-12-31 C001553 MCINTOSH CC 230 KV TIE LINE, 230, 1.27, 0 2023-01-01 2023-12-31 C001553 Piedmont-Forrest Corporation 2023-01-01 2023-12-31 C001553 219 BROAD RIVER STONE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Jobbing Work in Progress 2023-01-01 2023-12-31 C001553 794 HARMONY BLUE GRANITE #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1875 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 368 COLONIAL PIPELINE (Dacula), Distribution, Unattended 2023-12-31 C001553 152 BIG POPLAR, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (CC) 2023-12-31 C001553 7 ADAMS PM, Distribution, Unattended 2023-12-31 C001553 Deferred Revenue (a) 2023-12-31 C001553 516 DUBLIN, Distribution, Unattended 2023-12-31 C001553 0 ferc:ElectricUtilityMember 2023-12-31 C001553 1960 WHITEOAK, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1511 ROSWELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 226 BROOKLET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other, Net 2022-01-01 2022-12-31 C001553 273 CANYON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 621 FLAT SHOALS ROAD, Distribution, Unattended 2023-12-31 C001553 1962 WHITESTONE PD, Distribution, Unattended 2023-12-31 C001553 (2) TRANSMISSION, 2023-01-01 2023-12-31 C001553 State Income Tax, Income Tax, Georgia, 2023-01-01 2023-12-31 C001553 560 ELBERTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 99 AVONLEA, Distribution, Unattended 2023-12-31 C001553 1968 WILLIAMS CIRCLE SUBDIVISION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 740 GORDON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember Plant McIntosh - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 1326 PEACHTREE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Building Additions & Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 617 FITZGERALD, Transmission, Unattended 2023-12-31 C001553 1016 LOUISVILLE AREA #3 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 426 CSX TRANSPORTATION PM (Fitzgerald), Distribution, Unattended 2023-12-31 C001553 Sonny Solar, LLC, LU, 2023-01-01 2023-12-31 C001553 654 FORT GORDON SOLAR (IC-387), Generation, Attended 2023-01-01 2023-12-31 C001553 1791 TRENTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BOWEN SOUTH 230 KV LN, 230, 30.28, 211505 2023-01-01 2023-12-31 C001553 356 COCHRAN PRIMARY, Distribution, Unattended 2023-12-31 C001553 38 ALTO, Distribution, Unattended 2023-12-31 C001553 Enterprise Solutions System Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1499 ROCKY FORD ROAD, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (CT) 2023-01-01 2023-12-31 C001553 Workforce Reduction Programs 2023-12-31 C001553 1130 MILLIKEN (Lagrange), Distribution, Unattended 2023-12-31 C001553 550 EATONTON, Distribution, Unattended 2023-12-31 C001553 RENEWABLES AND GREEN ENERGY - DOCKET NO. 43107,43085, 43814, and 43985 2023-01-01 2023-12-31 C001553 1953 WHIRLWIND STEEL PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1064 MCBEAN ROAD, Distribution, Unattended 2023-12-31 C001553 Distribution Services (e) 2023-01-01 2023-12-31 C001553 Deferred Capitalized Interest on Nuclear 2022-12-31 C001553 697 GEORGIA MARBLE (Marble Hill), Distribution, Unattended 2023-12-31 C001553 1435 RALSTON PURINA MILLS (Gainesville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 226 BROOKLET, Distribution, Unattended 2023-12-31 C001553 1387 POWER LINE ROAD, Distribution, Unattended 2023-12-31 C001553 FLAT-GS Flat Bill - General Service 2023-01-01 2023-12-31 C001553 1353 PINE GROVE PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Plant Vogtle Units 3&4 Construction ferc:ElectricUtilityMember 2023-12-31 C001553 1875 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 1823 TYSON FOODS (Cumming), Distribution, Unattended 2023-12-31 C001553 1938 WEST CRAWFORDVILLE, Distribution, Unattended 2023-12-31 C001553 707 GEORGIA PACIFIC GYPSUM (Savannah), Distribution, Unattended 2023-12-31 C001553 1154 MORELAND AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1412 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1856 VIENNA PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 398 COOPER TOOLS, Distribution, Unattended 2023-12-31 C001553 4%ferc:ElectricUtilityMember 2022-12-31 C001553 513 DSM CHEMICALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1759 THOMASTON, Distribution, Unattended 2023-12-31 C001553 1145 MOLENA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1499 ROCKY FORD ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Communications Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 1850 VENUS THREAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 980 LEE HARRIS PM, Distribution, Unattended 2023-12-31 C001553 589 EVANS PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 916 JUNCTION CITY MINING PD, Distribution, Unattended 2023-12-31 C001553 81 ATLANTA WATER TREATMENT (Bolton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 861 INTERFOR (Baxley), Distribution, Unattended 2023-01-01 2023-12-31 C001553 260 CAGLES (Perry), Distribution, Unattended 2023-01-01 2023-12-31 C001553 500 DOLCO PACKAGING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 751 GRANITEVILLE (Sibley), Distribution, Unattended 2023-12-31 C001553 1295 PACES FERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 524 DUTCHTOWN ROAD, Distribution, Unattended 2023-12-31 C001553 1267 OCMULGEE STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1893 W. L. BONNELL #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 685 GARNETT RIDGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 624 FLINT RIVER HYDRO, Generation, Attended 2023-12-31 C001553 Burke 4th Series 1994 - 2.25% 2023-12-31 C001553 1571 SHAW INDUSTRIES (Milledgeville), Distribution, Unattended 2023-12-31 C001553 369 COLONIAL PIPELINE (Danielsville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1573 SHAW INDUSTRIES (Thomson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1991 WINDY HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 806 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 780 GWINNETT COUNTY WFP (Lanier), Distribution, Unattended 2023-12-31 C001553 Storm Assistance, Alabama Power Company 2023-01-01 2023-12-31 C001553 1052 MARSHALLVILLE, Distribution, Unattended 2023-12-31 C001553 470 DELTA AIRLINES #2, Distribution, Unattended 2023-12-31 C001553 564 ELLIJAY #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FORT VALLEY STATE UNIVERSITY 2023-12-31 C001553 1851 VERDERY STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 768 GREYSTONE GOLF #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 365 COLONIAL PIPELINE (Bremen), Distribution, Unattended 2023-12-31 C001553 Series 2007 A - 5.65% 2023-12-31 C001553 Georgia Power Company Rate Schedule Federal Energy Regulatory Commission (FERC) No. 793, Initial docket not available on eLibrary 2023-01-01 2023-12-31 C001553 400 COOSAWATTEE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2009 - 1.00% 2023-01-01 2023-12-31 C001553 Distribution Network Improvements - Miscellaneous 2023-01-01 2023-12-31 C001553 1006 LLOYD SHOALS HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 571 ENCORE RECYCLING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 EAST POINT #2 230 KV LN, 230, 4.54, 51850 2023-01-01 2023-12-31 C001553 2006 WRENS PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1964 WHITEWATER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WOODSTOCK 230 KV LN, , , 0 2023-01-01 2023-12-31 C001553 1336 PERIMETER CENTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 962 LAKE LANIER, Distribution, Unattended 2023-12-31 C001553 216 BRIAR VISTA, Distribution, Unattended 2023-12-31 C001553 BOWEN 2023-01-01 2023-12-31 C001553 1719 TALLAPOOSA, Distribution, Unattended 2023-12-31 C001553 288 CDC (Clifton Road), Distribution, Unattended 2023-01-01 2023-12-31 C001553 484 DITTLER BROTHERS, Distribution, Unattended 2023-12-31 C001553 417 CROOKED RIVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1098 MEADOWS SUBDIVISION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 163 BLEYLE AMERICA, Distribution, Unattended 2023-12-31 C001553 ALABAMA STATE LINE 230 KV L, 230, 32.9, 40061 2023-01-01 2023-12-31 C001553 893 JAMES SHORT PM, Distribution, Unattended 2023-12-31 C001553 1489 ROBINS AFB #2, Distribution, Unattended 2023-12-31 C001553 Gas MCINTOSH (CC) 2023-01-01 2023-12-31 C001553 578 ERCO WORLDWIDE, Distribution, Unattended 2023-12-31 C001553 116 BARTON CHAPEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1717 SYLVESTER PRIMARY, Transmission, Unattended 2023-12-31 C001553 937 KIMBALL BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 965 LAKE OCONEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 166 BLOOMINGDALE, Distribution, Unattended 2023-12-31 C001553 1501 ROME, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1873 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 1060 MARTIN MARIETTA (Tyrone), Distribution, Unattended 2023-12-31 C001553 Langdale - Retired (D) 2023-01-01 2023-12-31 C001553 Plant Bowen - Clean Air Compliance 2023-01-01 2023-12-31 C001553 1493 ROBINS AFB SOLAR (IC-491), Generation, Attended 2023-12-31 C001553 1094 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1972 WILLOW RUN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1041 MAIN STREET #2 PD, Distribution, Unattended 2023-12-31 C001553 738 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1866 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 ferc:LandAndRightsMember Lewiston Road Substation Site 2023-01-01 2023-12-31 C001553 1737 TEMPLE INDUSTRIES (Thomson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTPDTEOC Real Time Pricing Day Ahead - Time of Use 2023-01-01 2023-12-31 C001553 859 INLAND ROME, Distribution, Unattended 2023-12-31 C001553 1094 MCMANUS, Generation, Attended 2023-12-31 C001553 1137 MINOLA DRIVE, Distribution, Unattended 2023-12-31 C001553 240 BUFFALO ROAD, Distribution, Unattended 2023-12-31 C001553 538 EAST MACON, Distribution, Unattended 2023-12-31 C001553 222 BRODIE METER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1048 MARION SPENCE ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1949 WEST POINT FOUNDRY & MACHINE, Distribution, Unattended 2023-12-31 C001553 735 GOODSON ROAD #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 267 CAMP ODOM PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 115 BARTLETTS FERRY, Transmission, Unattended 2023-12-31 C001553 Georgia Power Company ferc:DecemberMember 2023-01-01 2023-12-31 C001553 1366 PLANTATION PIPELINE (Subligna), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1186 NACOOCHEE, Generation, Attended 2023-12-31 C001553 836 HOBBS PM, Distribution, Unattended 2023-12-31 C001553 Commitments ferc:ElectricUtilityMember 2023-12-31 C001553 706 GEORGIA PACIFIC (Warrenton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Replace Failed Equipment ferc:ElectricUtilityMember 2023-12-31 C001553 1215 NORTH HIGHLANDS, Generation, Attended 2023-01-01 2023-12-31 C001553 1054 MARTIN HEIGHTS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2022B - 5.125% 2023-12-31 C001553 1669 STANDRIDGE COLOR #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SCHERER 2023-12-31 C001553 2003 WRENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Sloane Drake 2023-01-01 2023-12-31 C001553 TUGALO, YONAH 115 KV, SSP, Overground 2023-01-01 2023-12-31 C001553 1127 MILLIKEN (Duncan Stewart) Lagrange, Distribution, Unattended 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 462 DECATUR COUNTY INDUSTRIAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1788 TRENCH SHORING SERVICES, Distribution, Unattended 2023-12-31 C001553 COVID-19 Costs 2023-01-01 2023-12-31 C001553 1171 MOUNT VERNON MILLS (Trion), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1612 SOUTH CLEVELAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 20 ALADDIN FIBER ONE #7 PD, Distribution, Unattended 2023-12-31 C001553 426 CSX TRANSPORTATION PM (Fitzgerald), Distribution, Unattended 2023-01-01 2023-12-31 C001553 613 FIFTY SECOND STREET, Distribution, Unattended 2023-12-31 C001553 1035 MAGNOLIA BLUFF, Distribution, Unattended 2023-12-31 C001553 Burke 2nd Series 1994 - 2.25% 2023-12-31 C001553 1683 STEEPLECHASE PM, Distribution, Unattended 2023-12-31 C001553 ScheduleCapitalStockExpenseAbstract 2023-01-01 2023-12-31 C001553 1316 PASCOE STEEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1809 TURPIN HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1279 OLD SAVANAH ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1627 SOUTH NORCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1447 REDMOND CIRCLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 914 JUNCTION CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 555 2023-01-01 2023-12-31 C001553 Plant Bowen - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 System Flow Projects ferc:ElectricUtilityMember 2023-12-31 C001553 996 LITE-N-TIE (Postell) PM, Distribution, Unattended 2023-12-31 C001553 2354, YONAH 2023-12-31 C001553 Kessel D. Stelling, Jr. 2023-01-01 2023-12-31 C001553 948 KINGS BAY SOLAR (IC-391), Generation, Attended 2023-01-01 2023-12-31 C001553 168 BLOSSOM CREEK, Distribution, Unattended 2023-12-31 C001553 591 FACTORY SHOALS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 S Dahlonega-Clermont Jct 500kv T/L 2023-01-01 2023-12-31 C001553 1275 OLD HICKORY, Distribution, Unattended 2023-12-31 C001553 218 BROAD RIVER FOREST PM, Distribution, Unattended 2023-12-31 C001553 Plant Hatch - Mechanical ferc:ElectricUtilityMember 2023-12-31 C001553 239 BUFFALO ROAD, Distribution, Unattended 2023-12-31 C001553 0 2023-01-01 2023-12-31 C001553 49 ANGLO AMERICAN CLAY TEMPORARY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 127 BEASLEY TIMBER #2 PD, Distribution, Unattended 2023-12-31 C001553 Series 2023A - 4.65% 2023-12-31 C001553 800 HARTWELL, Distribution, Unattended 2023-12-31 C001553 Rainbow Energy Marketing Corporation, OS, T4 2023-01-01 2023-12-31 C001553 873 J. M. HUBER (Reids), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1099 MEDUSA PORTLAND CEMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 637 FORREST LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1293 OWL HEAD #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1043 MANCHESTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 361 2023-01-01 2023-12-31 C001553 367 2023-01-01 2023-12-31 C001553 Plant Hatch - Electrical ferc:ElectricUtilityMember 2023-12-31 C001553 867 INTERSTATE PAPER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 183 BOLTON STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1789 TRENT TUBE, Distribution, Unattended 2023-12-31 C001553 312 CHICKAMAUGA, Distribution, Unattended 2023-12-31 C001553 1306 PALM STREET, Distribution, Unattended 2023-12-31 C001553 1516 ROYSTON MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 874 J. M. HUBER MINE #1 (Marble Hill) PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCINTOSH (BLACK) 230 KV LN, 230, 0.42, 0 2023-01-01 2023-12-31 C001553 1026 MABLETON, Distribution, Unattended 2023-12-31 C001553 577 ERCO WORLDWIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 682 GALLAGER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 179 BOLLING ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1 ABBEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember S Dahlonega-Clermont Jct 230kv T/L 2023-01-01 2023-12-31 C001553 56 APALACHEE AREA #1 PM (RETIRED), Distribution, Unattended 2023-12-31 C001553 1613 SOUTH COBB DRIVE, Distribution, Unattended 2023-12-31 C001553 Tariff Volume No. 5, Southern Companies OATT, ER20-1734-006 2023-01-01 2023-12-31 C001553 1400 PRINGLE ROAD, Distribution, Unattended 2023-12-31 C001553 Nuclear Decommissioning 2023-12-31 C001553 ASI DG Group A Solar Contracts, OS, 2023-01-01 2023-12-31 C001553 1176 MOUNTAIN VIEW, Distribution, Unattended 2023-12-31 C001553 1237 NORTH TIFTON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 600 FAYETTEVILLE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 638 FORREST LAKE, Distribution, Unattended 2023-12-31 C001553 995 LIQUID CARBONIC, Distribution, Unattended 2023-01-01 2023-12-31 C001553 41 AMERICUS, Transmission, Unattended 2023-12-31 C001553 477 DEVEREUX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1925 WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Lawrence L. Gellerstedt, III 2023-01-01 2023-12-31 C001553 725 GLENNVILLE, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Plant Hatch - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Dawson Crossing-S Dahlonega 500kv T/L 2023-12-31 C001553 Utoy Springs Substation Site ferc:LandAndRightsMember 2023-01-01 2023-12-31 C001553 1362 PLANTATION PIPELINE (Bremen), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Orlando Utilities Commission, OS, 2023-01-01 2023-12-31 C001553 611 FIFTEENTH STREET, Transmission, Unattended 2023-12-31 C001553 208 BOWEN PUMPING, Distribution, Attended 2023-12-31 C001553 Software Licensing 2022-12-31 C001553 MOODY AFB 2023-01-01 2023-12-31 C001553 1369 POMONA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1482 RIVERWOOD #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 393 CONYERS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 720 GERDAU, Distribution, Unattended 2023-12-31 C001553 1387 POWER LINE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 248 BURGESS PIGMENT #2 PD, Distribution, Unattended 2023-12-31 C001553 1151 MONTEZUMA, Distribution, Unattended 2023-12-31 C001553 Facility 2023-01-01 2023-12-31 C001553 Nuclear Fuel 2022-01-01 2022-12-31 C001553 284 CASTLEBERRY ROAD, Distribution, Unattended 2023-12-31 C001553 Gas and Electric Hedges 2022-12-31 C001553 2020 YONAH, Generation, Attended 2023-12-31 C001553 862 INTERNATIONAL PAPER (Gordon), Distribution, Unattended 2023-12-31 C001553 964 LAKE OCONEE, Distribution, Unattended 2023-12-31 C001553 592 FACTORY SHOALS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Dominion Energy, OS, T4 2023-01-01 2023-12-31 C001553 1024 M A INDUSTRIES, Distribution, Unattended 2023-12-31 C001553 602 FEDERAL PENITENTIARY, Distribution, Unattended 2023-12-31 C001553 435 DAHLONEGA PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 816 HAZLEHURST PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 593 FACTORY SHOALS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2009A - 5.95% 2023-01-01 2023-12-31 C001553 1270 OHOOPEE RIVER, Distribution, Unattended 2023-12-31 C001553 63 ARGOS (Atlanta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1508 ROSSIGNOL HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 929 KENNESAW, Distribution, Unattended 2023-12-31 C001553 1256 NUTRASWEET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1065 MCBEAN ROAD, Distribution, Unattended 2023-12-31 C001553 1076 MCINTOSH CC, Generation, Attended 2023-12-31 C001553 1958 WHITEMARSH ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 258 BUTLER STREET, Distribution, Unattended 2023-12-31 C001553 Plant McDonough - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 1557 SCOTT HUDGENS BUILDING, Distribution, Unattended 2023-12-31 C001553 116 BARTON CHAPEL, Distribution, Unattended 2023-12-31 C001553 1392 PRATT & WHITNEY, Distribution, Unattended 2023-12-31 C001553 1190 NATIONAL BEEF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 776 GULFSTREAM #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1365 PLANTATION PIPELINE (Neese), Distribution, Unattended 2023-01-01 2023-12-31 C001553 756 GREAT SOUTHWEST AMUSEMENT PARK, Distribution, Unattended 2023-12-31 C001553 ferc:SubsidiaryCompanySubheadingMember Southern Electric Generating Co. 2023-01-01 2023-12-31 C001553 2413, WALLACE DAM 2023-01-01 2023-12-31 C001553 1433 RAINBOW DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 439 DALTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1546 SCHERER UNIT 1, Generation, Attended 2023-01-01 2023-12-31 C001553 275 CARLTON RURAL PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1419 PUBLIC SAFETY TRAINING CENTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1611 SOUTH CHATTOOGA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1313 PARKENSON CHURCH ROAD PM, Distribution, Unattended 2023-12-31 C001553 773 GUARDIAN AUTOMOTIVE #1, Distribution, Unattended 2023-12-31 C001553 306 CHATTAHOOCHEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 335 CLEARWATER ROAD PM, Distribution, Unattended 2023-12-31 C001553 798 HARTSFIELD JACKSON, Distribution, Unattended 2023-12-31 C001553 Retiree Benefit Plans 2023-12-31 C001553 856 INDIAN TRACE PM, Distribution, Unattended 2023-12-31 C001553 1728 TANNER PM, Distribution, Unattended 2023-12-31 C001553 478 DEVEREUX, Distribution, Unattended 2023-12-31 C001553 MCCONNENELL ROAD 230KV, 230, 1.61, 0 2023-01-01 2023-12-31 C001553 NORTH TIFTON 230 KV LN, 230, 9.93, 20585 2023-01-01 2023-12-31 C001553 376 COLUMBUS FOUNDRY, Distribution, Unattended 2023-12-31 C001553 1211 NORTH FAIRMOUNT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Energy United Electric Membership Corporation, LU, T4 2023-01-01 2023-12-31 C001553 1229 NORTH ROCKMART, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1476 RIVER STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 559 ELANCO, Distribution, Unattended 2023-12-31 C001553 FPA-IND Fixed Pricing Alternative 2023-01-01 2023-12-31 C001553 1253 NORTHWINDS, Distribution, Unattended 2023-12-31 C001553 1449 REFUGE ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Business License, Other License And Fees Tax, Alabama,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (2nd Issuance) 2022-12-31 C001553 DOE Loan 3.860% - 2044 2023-12-31 C001553 1120 MILLEN, Distribution, Unattended 2023-12-31 C001553 1635 SOUTHEAST TOYOTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1385 POWDER SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 205 BOWEN, Generation, Attended 2023-12-31 C001553 Chattahoochee Hydro Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 1132 MILLIKEN (New Holland) Gainesville, Distribution, Unattended 2023-12-31 C001553 1469 RINGGOLD, Distribution, Unattended 2023-12-31 C001553 1433 RAINBOW DRIVE, Distribution, Unattended 2023-12-31 C001553 DOE Loan 3.072% - 2044 2023-01-01 2023-12-31 C001553 1780 TOMMY FIELDS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 954 KOYO BEARING, Distribution, Unattended 2023-12-31 C001553 Other General Plant ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1947 WEST MABLETON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1514 ROYSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 2.178% - 2044 2023-01-01 2023-12-31 C001553 1191 NATIONAL BEEF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:SubsidiaryCompanySubheadingMember 2023-01-01 2023-12-31 C001553 709 GEORGIA PORTS AUTHORITY, Distribution, Unattended 2023-12-31 C001553 OL-NGRE Outdoor Lighting 2023-01-01 2023-12-31 C001553 Protective Relay Modernization Project ferc:ElectricUtilityMember 2023-12-31 C001553 480 DIAMOND HILL AREA PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 331 CLARKSTON, Distribution, Unattended 2023-12-31 C001553 430 CUMMING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Contract Retention 2022-12-31 C001553 286 CASTLEBERRY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OperatingUtilityMember 2023-01-01 2023-12-31 C001553 MCMANUS 230 KV LN, 230, 6.21, 98405 2023-01-01 2023-12-31 C001553 339 CLOVERLEAF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1059 MARTIN MARIETTA (Martinez), Distribution, Unattended 2023-12-31 C001553 1295 PACES FERRY, Distribution, Unattended 2023-12-31 C001553 1905 WALTHOURVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1066 MCCREE PM, Distribution, Unattended 2023-12-31 C001553 157 BLACK CREEK, Distribution, Unattended 2023-12-31 C001553 FUTA, Payroll Tax, 0, 2022-12-31 C001553 509 DOUBLE CHURCHES ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Franchise Fees - 2023, Franchise Tax, Georgia, 2023-01-01 2023-12-31 C001553 1233 NORTH STATESBORO, Distribution, Unattended 2023-12-31 C001553 168 BLOSSOM CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Federal Income Tax @ 21% 2023-01-01 2023-12-31 C001553 1610 SOUTH CHATTOOGA, Transmission, Unattended 2023-12-31 C001553 Series 2017A - 5.00% 2023-12-31 C001553 NextEra Gulf, OS, 2023-01-01 2023-12-31 C001553 1185 NACOOCHEE, Generation, Attended 2023-01-01 2023-12-31 C001553 982 LESLIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1320 PAUL WINNIE PM, Distribution, Unattended 2023-12-31 C001553 1471 RISING FAWN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 749 GRADY FLOYD PM, Distribution, Unattended 2023-12-31 C001553 1749 THE ROCK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1965 WIEUCA ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 672 FURYS FERRY, Distribution, Unattended 2023-12-31 C001553 91 AUGUSTA NEWSPRINT, Distribution, Unattended 2023-12-31 C001553 1952 WHEELER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 132 BEKAERT STEEL WIRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCINTOSH (CT) 2023-12-31 C001553 1764 THOMSON PRIMARY, Transmission, Unattended 2023-12-31 C001553 580 ERICK CHURCH ROAD PM, Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember South Hall - Winder T/L 2023-01-01 2023-12-31 C001553 ROBINS AFB 2023-12-31 C001553 1973 WILLOW RUN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Heard 1st Series 2007 - Variable 2023-12-31 C001553 EAST DALTON, 230, 19.57, 374953 2023-01-01 2023-12-31 C001553 805 HATCH, Generation, Attended 2023-12-31 C001553 597 FAYETTEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1827 U.S. MARINE CORPS SUPPLY DEPOT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1181 MULKEY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 181 BOLTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember ferc:ElectricPlantInServiceMember 2023-01-01 2023-12-31 C001553 Estatoah - Retired (C) 2023-12-31 C001553 144 BERKELEY LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1074 MCINTOSH, Transmission, Unattended 2023-12-31 C001553 1245 NORTHSIDE DRIVE, Distribution, Unattended 2023-12-31 C001553 316 CHICOPEE WOODS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 546 EAST VIENNA, Distribution, Unattended 2023-12-31 C001553 191 BOULEVARD (Savannah), Transmission, Unattended 2023-12-31 C001553 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2023-01-01 2023-12-31 C001553 1153 MONTGOMERYVILLE, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Load Related System Improvements 2023-01-01 2023-12-31 C001553 CWIP Electric ferc:NonUtilityMember 2023-12-31 C001553 29 ALCOVY ROAD, Transmission, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember S Dahlonega-Clermont Jct 230kv T/L 2023-12-31 C001553 518 DULUTH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous contributions to capital 2023-01-01 2023-12-31 C001553 130 BEAVER DRIVE, Distribution, Unattended 2023-12-31 C001553 822 HERITAGE HILLS PM, Distribution, Unattended 2023-12-31 C001553 297 CENTRAL STATE HOSPITAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OtherUtilityMember Other (Specify) 2023-01-01 2023-12-31 C001553 925 KEDRON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1489 ROBINS AFB #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1828 U.S. POSTAL FACILITY (Hapeville), Distribution, Unattended 2023-12-31 C001553 192 BOWDON JUNCTION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1103 MEIGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1242 NORTHEAST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Mississippi,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 437 DAHLONEGA PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 991 LINDALE #2, Distribution, Unattended 2023-12-31 C001553 Burke 9th Series 1994 - 2.25% 2023-01-01 2023-12-31 C001553 RTPDPLLC Real Time Pricing Day Ahead - Power & Light Large 2023-01-01 2023-12-31 C001553 243 BUHLER QUALITY YARNS, Distribution, Unattended 2023-12-31 C001553 513 DSM CHEMICALS, Distribution, Unattended 2023-12-31 C001553 1370 POMONA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 701 GEORGIA PACIFIC (Durand), Distribution, Unattended 2023-12-31 C001553 Exelon Generation Company, LLC, OS, 2023-01-01 2023-12-31 C001553 Miscellaneous 2023-01-01 2023-03-31 C001553 414 CRAWFORDVILLE, Distribution, Unattended 2023-12-31 C001553 1511 ROSWELL, Distribution, Unattended 2023-12-31 C001553 618 FLAT CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 North Georgia Hydro Miscellaneous Additions 2023-01-01 2023-12-31 C001553 1022 LUMBER CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1669 STANDRIDGE COLOR #1, Distribution, Unattended 2023-12-31 C001553 1733 TAYLORSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 224 BROOKHAVEN BOULEVARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SOUTH GRIFFIN 230 KV LN, 230, 0, 0 2023-01-01 2023-12-31 C001553 KRAFT 230 KV (SAV), 230, 6.01, 2286 2023-01-01 2023-12-31 C001553 224 BROOKHAVEN BOULEVARD, Distribution, Unattended 2023-12-31 C001553 FUEL COST RECOVERY - DOCKET NO. 22403 and 44902 2023-01-01 2023-12-31 C001553 , 115, 4673.68, 410323 2023-01-01 2023-12-31 C001553 653 FORT GORDON HOSPITAL, Distribution, Unattended 2023-12-31 C001553 1755 THIELE KAOLIN (Wrens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1732 TATUM ROAD PM, Distribution, Unattended 2023-12-31 C001553 1436 RANDALL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 960 LAGRANGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 717 GERDAU, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1920 WATKINS WOODS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 432 CUTHBERT, Distribution, Unattended 2023-12-31 C001553 1657 SOUTHWIRE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 S MACON 230KV LN, , , 0 2023-01-01 2023-12-31 C001553 975 LANGBOARD (Quitman), Distribution, Unattended 2023-12-31 C001553 1376 PORTERDALE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE 1&2 2023-01-01 2023-12-31 C001553 1241 NORTHCREST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 114 BARTLETTS FERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 581 ETHICON, Distribution, Unattended 2023-12-31 C001553 746 GRABALL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1738 TEMPLE INDUSTRIES (Thomson), Distribution, Unattended 2023-12-31 C001553 Piedmont Forrest Corporation ferc:AdvancesOpenAccountMember 2022-12-31 C001553 639 FORREST ROAD (Columbus), Distribution, Unattended 2023-01-01 2023-12-31 C001553 761 GREENS MILL ROAD PM, Distribution, Unattended 2023-12-31 C001553 364 COLONIAL PIPELINE (Armuchee), Distribution, Unattended 2023-12-31 C001553 452 DAWSON INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 FICA-COVID 19 Federal, Payroll Tax, 0,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 490 DIXIE PIPELINE (Lumpkin), Distribution, Unattended 2023-12-31 C001553 Miscellaneous Transmission Substation Additions & Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 1096 MCRAE, Transmission, Unattended 2023-12-31 C001553 1352 PILGRIMS PRIDE (Industrial Boulevard), Distribution, Unattended 2023-01-01 2023-12-31 C001553 950 KINGSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1318 PATTON SEED PM, Distribution, Unattended 2023-12-31 C001553 ferc:NonUtilityMember CWIP NonElectric 2022-12-31 C001553 313 CHICKAMAUGA, Distribution, Unattended 2023-12-31 C001553 Solar: 2023-01-01 2023-12-31 C001553 1170 MOUNT VERNON MILLS (Cleveland), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont-Forrest Corporation 2023-12-31 C001553 2177, GOAT ROCK 2023-01-01 2023-12-31 C001553 459 DECATUR, Distribution, Unattended 2023-12-31 C001553 47 ANDERSONVILLE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Effingham 1st Series 2003 - Variable 2023-01-01 2023-12-31 C001553 DSM Over Recovery 2022-12-31 C001553 Georgia Power Company ferc:OctoberMember 2023-01-01 2023-12-31 C001553 1940 WEST DALLAS, Distribution, Unattended 2023-12-31 C001553 1292 OWENS ILLINOIS (Hamilton Boulevard), Distribution, Unattended 2023-12-31 C001553 1977 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 Environmental Remediation 2023-01-01 2023-12-31 C001553 103 BAKER PLACE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1844 US 1 RECYCLING, Distribution, Unattended 2023-12-31 C001553 1252 NORTHWEST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VARIOUS Tariff Customers VARIOUS Tariff Customers VARIOUS AD VARIOUS 0 2023-01-01 2023-12-31 C001553 Other 2023-01-01 2023-12-31 C001553 1642 SOUTHERN LNG, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Information Technology, Southern Company Services 2023-01-01 2023-12-31 C001553 110 BARNETT ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Westar Energy, Inc., OS, 2023-01-01 2023-12-31 C001553 1451 REIDS PRIMARY, Transmission, Unattended 2023-12-31 C001553 727 GOAT ROCK #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 463 DEKALB COUNTY SCOTT CANDLER WFP, Distribution, Unattended 2023-12-31 C001553 1691 STONEWALL STREET, Distribution, Unattended 2023-12-31 C001553 1981 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 401 COOSAWATTEE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 551 EATONTON, Distribution, Unattended 2023-12-31 C001553 2011 YAMAHA, Distribution, Unattended 2023-12-31 C001553 1854 VIDALIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1203 NORTH ATHENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Franchise Fees - 2023, Franchise Tax, Georgia, 2023-12-31 C001553 888 JACK MCDONOUGH CC #6, Generation, Attended 2023-12-31 C001553 1582 SINCLAIR DAM HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 679 GAINESVILLE #2, Distribution, Unattended 2023-12-31 C001553 Invenergy, LU, 2023-01-01 2023-12-31 C001553 748 GRADY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company Rate Schedule No. 836 , ER24-457-000 2023-01-01 2023-12-31 C001553 Municipal Electric Authority of Ga (MEAG) OS 2023-01-01 2023-12-31 C001553 207 BOWEN NPDES, Distribution, Attended 2023-12-31 C001553 1301 PACTIV #3 PD, Distribution, Unattended 2023-12-31 C001553 1931 WELLS ALUMINUM #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1053 MARTA ANNEX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 19 ALADDIN FIBER ONE #6 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 233 BUCKHEAD (Madison) (NEW), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1906 WANSLEY, Generation, Attended 2023-01-01 2023-12-31 C001553 476 DERING CIRCLE 230, Distribution, Unattended 2023-12-31 C001553 301 CERTAINTEED (Social Circle), Distribution, Unattended 2023-01-01 2023-12-31 C001553 740 GORDON, Transmission, Unattended 2023-12-31 C001553 Vogtle 3&4 Construction 2022-12-31 C001553 1 ABBEVILLE, Distribution, Unattended 2023-12-31 C001553 263 CALHOUN COUNTY PRISON #2 PD (West), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1092 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1213 NORTH GRIFFIN, Distribution, Unattended 2023-12-31 C001553 1073 MCINTOSH, Transmission, Unattended 2023-01-01 2023-12-31 C001553 18 ALADDIN FIBER ONE #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1701 SUNSHINE BISCUIT (Columbus), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Utility Services Contracts (d) 2023-01-01 2023-12-31 C001553 4 ACORN CREEK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 664 FRANKLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 City of Troy, Alabama, OS, 2023-01-01 2023-12-31 C001553 692 GEORGIA BOARD OF CORRECTIONS, Distribution, Unattended 2023-12-31 C001553 320 CHINCHILLA ROAD PM, Distribution, Unattended 2023-12-31 C001553 1007 LLOYD SHOALS HYDRO, Generation, Attended 2023-12-31 C001553 SLAPPEY DRIVE 230 KV, 115, , 105970 2023-01-01 2023-12-31 C001553 1541 SCHERER FGD 1/2, Generation, Attended 2023-01-01 2023-12-31 C001553 Misc GSU 2023-01-01 2023-12-31 C001553 1328 PEACHTREE CORNERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Balancing Operating Reserve 2023-01-01 2023-12-31 C001553 1371 PONCE DE LEON, Distribution, Unattended 2023-12-31 C001553 1805 TRUMAN PARKWAY, Distribution, Unattended 2023-12-31 C001553 FICA-COVID 19 State, Payroll Tax, 0, 2023-12-31 C001553 1748 THE BRIDGE CHURCH, Distribution, Unattended 2023-12-31 C001553 1976 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 RTDTEOI Real Time Pricing Day Ahead - Time Of Use - Energy Only 2023-01-01 2023-12-31 C001553 Plant Wilson CT - Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1798 TRION, Distribution, Unattended 2023-12-31 C001553 913 JONESBORO, Distribution, Unattended 2023-12-31 C001553 1728 TANNER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ROW Services Perfection ferc:ElectricUtilityMember 2023-12-31 C001553 124 BAXLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1121 MILLEN AREA #2 PM, Distribution, Unattended 2023-12-31 C001553 494 DIXIE PIPELINE (Shiloh), Distribution, Unattended 2023-12-31 C001553 1363 PLANTATION PIPELINE (Doraville), Distribution, Unattended 2023-12-31 C001553 1883 VOGTLE 3&4 500KV, Generation, Attended 2023-12-31 C001553 1191 NATIONAL BEEF, Distribution, Unattended 2023-12-31 C001553 737 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-12-31 C001553 MEAG PSSA, OS, 2023-01-01 2023-12-31 C001553 1615 SOUTH DAHLONEGA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1336 PERIMETER CENTER, Distribution, Unattended 2023-12-31 C001553 RTPDPLLI Real Time Pricing Day Ahead - Power & Light Large 2023-01-01 2023-12-31 C001553 572 ENGELHARD (Gordon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1484 ROBERTS ROAD, Distribution, Unattended 2023-12-31 C001553 1311 PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1524 SAINT SIMONS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1850 VENUS THREAD, Distribution, Unattended 2023-12-31 C001553 PLL-C Power & Light - Large 2023-01-01 2023-12-31 C001553 903 JEWELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1091 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1632 SOUTH TIFTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2023, Property Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1837 UNITED PARCEL SERVICE, Distribution, Unattended 2023-12-31 C001553 1725 TALLULAH FALLS, Generation, Attended 2023-01-01 2023-12-31 C001553 Miscellaenous Transmission Line Replacements 2023-01-01 2023-12-31 C001553 1872 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 46 ANCHOR GLASS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 716 GEORGIA TUBING, Distribution, Unattended 2023-12-31 C001553 Series 2013A - 4.3% 2023-01-01 2023-12-31 C001553 1088 MCMANUS, Generation, Attended 2023-12-31 C001553 RTPHPLLI Real Time Pricing Hour Ahead - Power & Light Large 2023-01-01 2023-12-31 C001553 674 GAILLARD PRIMARY, Transmission, Unattended 2023-12-31 C001553 1800 TRONOX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 753 GRAPHIC PACKAGING (Augusta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 206 BOWEN, Generation, Attended 2023-12-31 C001553 210 BOXWOOD, Distribution, Unattended 2023-12-31 C001553 1569 SHAW INDUSTRIES #2 PD (Trenton), Distribution, Unattended 2023-12-31 C001553 133 BELAIR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1163 MOSSY BRANCH BATTERY STORAGE, Generation, Attended 2023-12-31 C001553 791 HARD LABOR CREEK ESTATES PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 741 GORDON ROAD, Distribution, Unattended 2023-12-31 C001553 Franchise Fees - 2022, Franchise Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1002 LITTLE RIVER, Distribution, Unattended 2023-12-31 C001553 1811 TWIN CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1401 PROCTER & GAMBLE (Albany), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 9th Series 1994 - 2.25% 2023-12-31 C001553 1343 PETTIT CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1565 SEVENTH AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 812 HATCH SITE #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Southern Electric Generating Company 2023-01-01 2023-12-31 C001553 350 COBB MARIETTA WATER (Wyckoff), Distribution, Unattended 2023-12-31 C001553 788 HAMILTON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCDONOUGH CC #5 TIE LINE, 230, 0.77, 0 2023-01-01 2023-12-31 C001553 Customer Data Usage 2023-12-31 C001553 1210 NORTH DRUID HILLS, Distribution, Unattended 2023-12-31 C001553 0, ROCKY MOUNTAIN 2023-12-31 C001553 837 HOGANSVILLE, Distribution, Unattended 2023-12-31 C001553 Non-Cumulative, Par Value $25 Per Share 2023-01-01 2023-12-31 C001553 Prepaid Rent for Outdoor Lighting (c) 2022-12-31 C001553 995 LIQUID CARBONIC, Distribution, Unattended 2023-12-31 C001553 1115 MIDVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1812 TWIN LAKES, Transmission, Unattended 2023-01-01 2023-12-31 C001553 487 DIXIE PECAN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Distribution Projects Contribution In Aid Of Construction Offset 2023-01-01 2023-12-31 C001553 WARNER ROBINS 2023-01-01 2023-12-31 C001553 1863 VISY PAPER, Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember S Dahlonega-Clermont Jct 500kv T/L 2023-12-31 C001553 1250 NORTHWEST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1684 STEVENS CREEK, Transmission, Unattended 2023-12-31 C001553 NANTR-OATT-FERC-AttK-Ntwk-Oth, OS, 2023-01-01 2023-12-31 C001553 2336, LLOYD SHOALS 2023-01-01 2023-12-31 C001553 1996 WOODBINE, Distribution, Unattended 2023-12-31 C001553 1679 STATESBORO PRIMARY, Distribution, Unattended 2023-12-31 C001553 MARTINS LANDING 230KV, 230, 6.12, 1274651 2023-01-01 2023-12-31 C001553 652 FORT GORDON #2, Distribution, Unattended 2023-12-31 C001553 Mobile Device Billing 2023-01-01 2023-12-31 C001553 1929 WAYNESBORO PRIMARY, Transmission, Unattended 2023-12-31 C001553 ROCK SPRINGS-TVA 230 KV LN, 230, 27.9, 285837 2023-01-01 2023-12-31 C001553 212 BRADLEY INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 1817 TYBEE ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Transmission Line Hwy Change 2023-01-01 2023-12-31 C001553 1519 SAGE AUTOMOTIVE INTERIORS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Retiree Benefit Plans 2023-12-31 C001553 BOWEN, UNION CITY #1 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 1153 MONTGOMERYVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1459 RENESSENZ, Distribution, Unattended 2023-12-31 C001553 66 ARMSTRONG WORLD INDUSTRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 POWER RESEARCH INSTITUTE, Electric Power Research Institute 506 2023-01-01 2023-12-31 C001553 1596 SOCIAL CIRCLE, Distribution, Unattended 2023-12-31 C001553 1356 PINSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 608 FIELDALE FARMS (Cornelia), Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Alabama, 2023-12-31 C001553 924 KATHWOOD DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Orlando Utilities Commission, OS, T4 2023-01-01 2023-12-31 C001553 Duke Energy Florida, OS, T4 2023-01-01 2023-12-31 C001553 1268 OCONEE PD, Distribution, Unattended 2023-12-31 C001553 1808 TUGALO, Generation, Attended 2023-01-01 2023-12-31 C001553 26 ALADDIN MILLS #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 STOCKBRIDGE 230KV, 230, 5.12, 0 2023-01-01 2023-12-31 C001553 1803 TROY ALDRIDGE PM, Distribution, Unattended 2023-12-31 C001553 1031 MADRAS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1403 PROFILE EXTRUSIONS PD, Distribution, Unattended 2023-12-31 C001553 911 JOHNSON FERRY ROAD, Distribution, Unattended 2023-12-31 C001553 Miscellaneous Minor Projects (Less Than $1 Million)ferc:ElectricUtilityMember 2023-12-31 C001553 1235 NORTH THOMSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 775 GULFSTREAM #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Prepaid Rent for Outdoor Lighting (c) 2023-12-31 C001553 Series 2017B - 3.25% 2023-01-01 2023-12-31 C001553 913 JONESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 612 FIFTEENTH STREET, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Cumulative Preferred, Par Value $100 Per Share 2023-12-31 C001553 ferc:OtherUtilityOrNonutilityMember 0 2023-01-01 2023-12-31 C001553 APS-IND Agricultural Process Service 2023-01-01 2023-12-31 C001553 673 GA ARMY NATIONAL GUARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 NTE Carolinas, OS, T4 2023-01-01 2023-12-31 C001553 912 JONES CREEK, Distribution, Unattended 2023-12-31 C001553 SUTA, Payroll Tax, Alabama, 2023-12-31 C001553 722 GIBSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2005 WRENS PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 830 HIGHWAY 515 PM (Ellijay), Distribution, Unattended 2023-12-31 C001553 904 JIMMY CARGILL PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1178 MRS. SMITHS BAKERIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1282 OLIVER DAM HYDRO, Generation, Attended 2023-12-31 C001553 Business License, Other License And Fees Tax, Mississippi, 2022-12-31 C001553 721 GERDAU, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1608 SOUTH AUGUSTA, Transmission, Unattended 2023-12-31 C001553 68 ARTESIAN STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 89 AUGUSTA AREA #4 PM, Distribution, Unattended 2023-12-31 C001553 1443 REBECCA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 232 BRUNSWICK, Distribution, Unattended 2023-12-31 C001553 977 LAST LAKE, Distribution, Unattended 2023-12-31 C001553 Kimberly S. Greene 2023-01-01 2023-12-31 C001553 City of Evergreen City of Evergreen City of Evergreen FNO N/A 10 2023-01-01 2023-12-31 C001553 1963 WHITESTONE PD, Distribution, Unattended 2023-12-31 C001553 Other Power Generation, Southern Nuclear Operating Company 2023-01-01 2023-12-31 C001553 2413, WALLACE DAM 2023-01-01 2023-12-31 C001553 952 KIRKHILL MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 157 BLACK CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 771 GROVE POINT ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1845 UVALDA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2177, OLIVER DAM 2023-01-01 2023-12-31 C001553 1841 UNIVERSITY OF WEST GEORGIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 889 JACK MCDONOUGH CC #6, Generation, Attended 2023-01-01 2023-12-31 C001553 296 CENTRAL AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 992 LINDBERGH, Distribution, Unattended 2023-12-31 C001553 1880 VOGTLE 3&4 500KV, Generation, Attended 2023-01-01 2023-12-31 C001553 , 2023-01-01 2023-12-31 C001553 RTPDHLF RTP Day Ahead - Time of Use High Load Factor 2023-01-01 2023-12-31 C001553 603 FENWICK STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2001 WRENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 175 BOGART, Distribution, Unattended 2023-12-31 C001553 648 FORT GAINES, Distribution, Unattended 2023-12-31 C001553 118 BASE MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 1688 STOCKBRIDGE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1862 VIRGINIA AVENUE, Distribution, Unattended 2023-12-31 C001553 DOE Loan 3.142% - 2044 2023-01-01 2023-12-31 C001553 1070 MCDONOUGH, Distribution, Unattended 2023-12-31 C001553 Chattahoochee Hydro Miscellaneous Additions 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Northwest Region Operating HQ Site 2023-12-31 C001553 319 CHINA HILL ROAD PM, Distribution, Unattended 2023-12-31 C001553 25 ALADDIN MILLS #3, Distribution, Unattended 2023-12-31 C001553 1408 PROPEX #2 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1446 RED TOP MOUNTAIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1925 WAYCROSS, Distribution, Unattended 2023-12-31 C001553 1961 WHITESBURG, Distribution, Unattended 2023-01-01 2023-12-31 C001553 268 CANDLER AREA PM, Distribution, Unattended 2023-12-31 C001553 SOWEGA 230 KV LN, 230, 8.98, 156966 2023-01-01 2023-12-31 C001553 Plant Hatch - Controls 2023-01-01 2023-12-31 C001553 1745 TEXTRON SPECIALITY PRODUCTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 878 J. WILLFORD PM (Vesta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 969 LAKE TYRONE PD, Distribution, Unattended 2023-12-31 C001553 1209 NORTH DRUID HILLS, Distribution, Unattended 2023-12-31 C001553 1527 SANDERSON FARMS, Distribution, Unattended 2023-12-31 C001553 SWEET BOT-SUWANEE 230KV, 230, 28.27, 4281225 2023-01-01 2023-12-31 C001553 1630 SOUTH OGLETHORPE, Distribution, Unattended 2023-12-31 C001553 1035 MAGNOLIA BLUFF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1588 SLAPPEY DRIVE, Distribution, Unattended 2023-12-31 C001553 Series 2023B - 4.95% 2023-12-31 C001553 1250 NORTHWEST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 1790 TRENTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Sustaining Power Solutions LLC, LU, 2023-01-01 2023-12-31 C001553 662 FOX TRACE PM, Distribution, Unattended 2023-12-31 C001553 160 BLACKWELLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1742 TERRORA HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 137 BELVEDERE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1657 SOUTHWIRE #2, Distribution, Unattended 2023-12-31 C001553 374 COLUMBUS, Distribution, Unattended 2023-12-31 C001553 778 GUM CREEK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1734 TAZEWELL, Transmission, Unattended 2023-12-31 C001553 940 KIMBALL BRIDGE, Distribution, Unattended 2023-12-31 C001553 FUEL COST RECOVERY - DOCKET NO. 22403 and 44902 2023-12-31 C001553 400 COOSAWATTEE, Transmission, Unattended 2023-12-31 C001553 585 EUREKA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 90 AUGUSTA CORPORATE PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Non-Cumulative, Par Value $100 Per Share 2023-12-31 C001553 1068 MCDONOUGH, Distribution, Unattended 2023-12-31 C001553 ALTERNATIVE RATE PLAN - 2023-12-31 C001553 Burke 5th Series 1994 - 2.15% 2023-01-01 2023-12-31 C001553 1713 SWEETBOTTOM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 713 GEORGIA SYNTHETICS, Distribution, Unattended 2023-12-31 C001553 1486 ROBERTS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 774 GULFSTREAM #1, Distribution, Unattended 2023-12-31 C001553 1452 REIDSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1171 MOUNT VERNON MILLS (Trion), Distribution, Unattended 2023-12-31 C001553 1108 MERIWETHER PARK, Distribution, Unattended 2023-12-31 C001553 Deferred Compensation 2023-12-31 C001553 502 DONNA WAY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1010 LOCKHEED MARTIN #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 853 HUTCHINSON ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 373 COLQUITT, Distribution, Unattended 2023-12-31 C001553 1672 STANDRIDGE COLOR #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 819 HEMPHILL WATER TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2023-12-31 C001553 1078 MCINTOSH CT, Generation, Attended 2023-01-01 2023-12-31 C001553 1147 MONK ROAD, Distribution, Unattended 2023-12-31 C001553 1710 SWAINSBORO PRIMARY, Distribution, Unattended 2023-12-31 C001553 2354, MATHIS-TERRORA 2023-12-31 C001553 77 ATHENS OPERATING PM, Distribution, Unattended 2023-12-31 C001553 752 GRAPHIC PACKAGING, Distribution, Unattended 2023-12-31 C001553 1829 U.S. POSTAL SERVICE, Distribution, Unattended 2023-12-31 C001553 795 HARRISON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1198 NIPPER PM, Distribution, Unattended 2023-12-31 C001553 1331 PEEPLES VALLEY, Distribution, Unattended 2023-12-31 C001553 FORTSO, N TIFTON 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 1342 PETTIT CREEK, Distribution, Unattended 2023-12-31 C001553 838 HOLLY DRIVE INDUSTRIAL, Distribution, Unattended 2023-12-31 C001553 Deferred Income Taxes 2023-01-01 2023-12-31 C001553 182 BOLTON STREET, Distribution, Unattended 2023-12-31 C001553 745 GOUGH CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 491 DIXIE PIPELINE (Milner), Distribution, Unattended 2023-01-01 2023-12-31 C001553 850 HUNTSMAN PIGMENTS, Distribution, Unattended 2023-12-31 C001553 829 HIGHWAY 51 PM (Hartwell), Distribution, Unattended 2023-12-31 C001553 1521 SAINT MARYS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1207 NORTH CONYERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 566 ELLIJAY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 LESS COST BILLED TO OTHERS, 2023-01-01 2023-12-31 C001553 969 LAKE TYRONE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 343 COBB, Distribution, Unattended 2023-12-31 C001553 North Carolina EMC, OS, 2023-01-01 2023-12-31 C001553 413 CRAWFORD, Distribution, Unattended 2023-12-31 C001553 1720 TALLASSEE ROAD SCHOOL PD, Distribution, Unattended 2023-12-31 C001553 Monroe 2nd Series 2006 - Variable 2023-12-31 C001553 293 CEDAR VILLAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 495 DIXIE ROAD, Distribution, Unattended 2023-12-31 C001553 781 GWINNETT COUNTY WFP (Shoal Creek), Distribution, Unattended 2023-12-31 C001553 1572 SHAW INDUSTRIES (Thomson), Distribution, Unattended 2023-12-31 C001553 1131 MILLIKEN (New Holland) Gainesville, Distribution, Unattended 2023-12-31 C001553 1599 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 396 2023-01-01 2023-12-31 C001553 1334 PEMBROKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 84 ATLANTA WATER WORKS (Moores Mill), Distribution, Unattended 2023-12-31 C001553 574 ENGELHARD (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 347 COBB MARIETTA WATER #2 (Johnson Ferry), Distribution, Unattended 2023-01-01 2023-12-31 C001553 792 HARGROVE ROAD, Distribution, Unattended 2023-12-31 C001553 834 HIRAM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 All Other General Accounts ferc:DirectPayrollDistributionMember 2023-01-01 2023-12-31 C001553 Mackinaw Power LLC, LU, 2023-01-01 2023-12-31 C001553 287 CAVE SPRING #2, Distribution, Unattended 2023-12-31 C001553 1860 VINEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 810 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:EquityContributionMember 2023-12-31 C001553 615 FIRST UNITED ETHANOL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 466 DEKALB COUNTY WATER (Holcombe Bridge), Distribution, Unattended 2023-12-31 C001553 724 GILMAN PAPER (Fitzgerald), Distribution, Unattended 2023-12-31 C001553 978 LAWRENCEVILLE HIGHWAY, Distribution, Unattended 2023-12-31 C001553 606 FIELDALE FARMS #1 (Murrayville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Line Additions & Improvements 2023-01-01 2023-12-31 C001553 1813 TWIN LAKES, Transmission, Unattended 2023-01-01 2023-12-31 C001553 RTDPLSC RTP Day Ahead - Power & Light Supplier Choice 2023-01-01 2023-12-31 C001553 416 CREEKWOOD SUBDIVISION PM, Distribution, Unattended 2023-12-31 C001553 1675 STATENVILLE PD, Distribution, Unattended 2023-12-31 C001553 140 BENDIX FRICTION MATERIALS, Distribution, Unattended 2023-12-31 C001553 Short-Term Borrowings 2023-01-01 2023-12-31 C001553 176 BOJO, Distribution, Unattended 2023-12-31 C001553 1546 SCHERER UNIT 1, Generation, Attended 2023-12-31 C001553 2004 WRENS AREA #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1308 PALMYRA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Minor Projects (Less Than $1 Million) 2023-01-01 2023-12-31 C001553 Long-Term Service Agreement 2023-12-31 C001553 1585 SIX MILE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember McDonough-East Point 230 KV 2023-12-31 C001553 1529 SANDY BOTTOM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1352 PILGRIMS PRIDE (Industrial Boulevard), Distribution, Unattended 2023-12-31 C001553 SCH School Service 2023-01-01 2023-12-31 C001553 2014 YATES 6&7, Generation, Attended 2023-12-31 C001553 951 KIOKEE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1039 MAGNOLIA ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 772 GROVETOWN PRIMARY, Distribution, Unattended 2023-12-31 C001553 1830 U.S. VETERANS HOSPITAL (Dublin), Distribution, Unattended 2023-12-31 C001553 State Income Tax, Income Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1271 OLD ALABAMA ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 583 EUCHEE CREEK, Distribution, Unattended 2023-12-31 C001553 1309 PALMYRA, Distribution, Unattended 2023-12-31 C001553 SAS-COM Seasonal Agricultural Service 2023-01-01 2023-12-31 C001553 415 CREEK PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 420 CROSSROADS PARKWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1681 STATESBORO PRIMARY, Distribution, Unattended 2023-12-31 C001553 169 BLUE CIRCLE AGGREGATES #1 (Lithonia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 108 BARCO #1 (TALLAPOOSA) PD, Distribution, Unattended 2023-12-31 C001553 ferc:DirectPayrollDistributionMember Office Building 2023-01-01 2023-12-31 C001553 1017 LOUISVILLE AREA #7 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 101 BAINBRIDGE, Distribution, Unattended 2023-12-31 C001553 703 GEORGIA PACIFIC (Monticello), Distribution, Unattended 2023-01-01 2023-12-31 C001553 KLONDIKE, 230, 5.6, 79333 2023-01-01 2023-12-31 C001553 1012 LOCKHEED MARTIN WIND TUNNEL, Distribution, Unattended 2023-12-31 C001553 1297 PACKAGING CORPORATION (Macon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 229 BROWN BROTHERS SAND PIT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 42 AMERICUS, Transmission, Unattended 2023-12-31 C001553 1162 MORNINGSIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1696 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1610 SOUTH CHATTOOGA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1384 POULAN, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Software Purchases and Upgrades 2023-01-01 2023-12-31 C001553 1122 MILLEN AREA #3 PM, Distribution, Unattended 2023-12-31 C001553 RTDRN-C RTP Day Ahead - Revenue Neutral 2023-01-01 2023-12-31 C001553 52 ANTIOCH ROAD, Distribution, Unattended 2023-12-31 C001553 1356 PINSON, Distribution, Unattended 2023-12-31 C001553 1383 POULAN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Commitments 2023-01-01 2023-12-31 C001553 231 BROWN FARM ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 938 KIMBALL BRIDGE, Distribution, Unattended 2023-12-31 C001553 272 CANTON #2, Distribution, Unattended 2023-12-31 C001553 320 CHINCHILLA ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 388 CONLEY CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1955 WHITE BLUFF, Transmission, Unattended 2023-12-31 C001553 646 FORT BENNING #2, Transmission, Unattended 2023-12-31 C001553 722 GIBSON, Distribution, Unattended 2023-12-31 C001553 1224 NORTH METTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1554 SCHERER UNIT 4, Generation, Attended 2023-01-01 2023-12-31 C001553 1952 WHEELER ROAD, Distribution, Unattended 2023-12-31 C001553 478 DEVEREUX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Distribution Line Improvements 2023-01-01 2023-12-31 C001553 1975 WILMINGTON ISLAND, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Constellation Energy, LU, 2023-01-01 2023-12-31 C001553 Mid Georgia Cogen LP, OS, 2023-01-01 2023-12-31 C001553 Non-Cumulative, Par Value $100 Per Share 2023-01-01 2023-12-31 C001553 720 GERDAU, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE 3&4, 230 KV RAT A LINE, SSP, Overground 2023-01-01 2023-12-31 C001553 2022 YOUNG STATION, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1311 PARK, Distribution, Unattended 2023-12-31 C001553 112 BARTLETTS FERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Eagle Energy Partners I, L.P., OS, T4 2023-01-01 2023-12-31 C001553 1081 MCINTOSH CT, Generation, Attended 2023-01-01 2023-12-31 C001553 Associated Energy Cooperative Inc., OS, 2023-01-01 2023-12-31 C001553 1558 SCOTTDALE, Distribution, Unattended 2023-12-31 C001553 443 DAVIDSON MINERAL (Lithonia), Distribution, Unattended 2023-12-31 C001553 256 BUTLER, Distribution, Unattended 2023-12-31 C001553 1676 STATESBORO, Distribution, Unattended 2023-12-31 C001553 Increases (Decreases) Due to Miscellaneous Paid-In Capital 2023-01-01 2023-12-31 C001553 RTPDPLMC Real Time Pricing Day Ahead - Power & Light Medium 2023-01-01 2023-12-31 C001553 15TH ST 230 KV, 115, 1.23, 497580 2023-01-01 2023-12-31 C001553 1815 TY TY PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 321 CHLORIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 711 GEORGIA SQUARE, Distribution, Unattended 2023-12-31 C001553 TC Traffic Control 2023-01-01 2023-12-31 C001553 1334 PEMBROKE, Distribution, Unattended 2023-12-31 C001553 831 HILL STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 TOURN-I Time of Use Revenue Neutral 2023-01-01 2023-12-31 C001553 RTPDSCH Real Time Pricing Day Ahead - School Load Management 2023-01-01 2023-12-31 C001553 475 DERING CIRCLE 115, Distribution, Unattended 2023-12-31 C001553 747 GRADY, Distribution, Unattended 2023-12-31 C001553 FICA, Payroll Tax, 0, 2022-12-31 C001553 1734 TAZEWELL, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1786 TRANSCO, Distribution, Unattended 2023-12-31 C001553 355 2023-01-01 2023-12-31 C001553 490 DIXIE PIPELINE (Lumpkin), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (2nd Issuance) 2023-01-01 2023-12-31 C001553 682 GALLAGER PM, Distribution, Unattended 2023-12-31 C001553 784 HAHIRA, Distribution, Unattended 2023-12-31 C001553 1721 TALLULAH FALLS, Generation, Attended 2023-01-01 2023-12-31 C001553 VOGTLE, MCINTOSH-THALMANN 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 985 LEXINGTON COMPONENTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 684 GARDEN CITY TERMINAL WEST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE SWITCHING 230-KV, 230, 1.02, 0 2023-01-01 2023-12-31 C001553 624 FLINT RIVER HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 563 ELLERSLIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Eagle Energy Partners I, L.P., OS, 2023-01-01 2023-12-31 C001553 Simon Solar Farm, LU, 2023-01-01 2023-12-31 C001553 VOGTLE 3 Nuclear 2023-01-01 2023-12-31 C001553 31 ALDORA MILLS #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1951 WEYERHAEUSER (Savannah), Distribution, Unattended 2023-12-31 C001553 South Mississippi Electric Power Association, OS, 2023-01-01 2023-12-31 C001553 1287 ORANGE HILL, Distribution, Unattended 2023-12-31 C001553 Cash Surrender Value Insurance (a) 2023-01-01 2023-12-31 C001553 147 BIBB MANUFACTURING (Percale), Distribution, Unattended 2023-12-31 C001553 217 BRIDGEPORT BRASS, Distribution, Unattended 2023-12-31 C001553 1149 MONROE, Distribution, Unattended 2023-12-31 C001553 1591 SMITHVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1611 SOUTH CHATTOOGA, Transmission, Unattended 2023-12-31 C001553 172 BOAT ROCK ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 930 KERRY #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Vehicle Fleet Services, Southern Company Services 2023-01-01 2023-12-31 C001553 323 CHOKEE PLANTATION PM, Distribution, Unattended 2023-12-31 C001553 1893 W. L. BONNELL #3, Distribution, Unattended 2023-12-31 C001553 712 GEORGIA STATE PATROL - FAA BEACON PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 900 JERED BROWN BROTHERS, Distribution, Unattended 2023-12-31 C001553 , Advanced Power Plant 549 2023-01-01 2023-12-31 C001553 1013 LONG CANE, Distribution, Unattended 2023-12-31 C001553 1ST AVE COLS 230 KV LN, 230, 10.67, 43273 2023-01-01 2023-12-31 C001553 1307 PALMER CREEK, Distribution, Unattended 2023-12-31 C001553 565 ELLIJAY LUMBER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTDPLSI RTP Day Ahead/PLS-IND 2023-01-01 2023-12-31 C001553 424 CSX INTERMODAL (Fairburn), Distribution, Unattended 2023-12-31 C001553 780 GWINNETT COUNTY WFP (Lanier), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1726 TALMO TAP PD, Distribution, Unattended 2023-12-31 C001553 1473 RIVER PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 820 HERCULES (Covington), Distribution, Unattended 2023-01-01 2023-12-31 C001553 All Other General Accounts 2023-01-01 2023-12-31 C001553 891 JACKSON COUNTY HEALTH CENTER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1230 NORTH SHALLOWFORD ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Mobile Device Billing 2022-12-31 C001553 Grid Investment ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 876 J. T. RYERSON & SON #1, Distribution, Unattended 2023-12-31 C001553 TOUGSD-I Time of Use - General Service Demand 2023-01-01 2023-12-31 C001553 1405 PROPEX #1 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Bowen - Clean Air Compliance ferc:ElectricUtilityMember 2023-12-31 C001553 1325 PEACHTREE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCMANUS 3 & 4 2023-01-01 2023-12-31 C001553 Miscellaneous Deferred Debits 2023-01-01 2023-12-31 C001553 Santa Rosa, OS, 2023-01-01 2023-12-31 C001553 564 ELLIJAY #2, Distribution, Unattended 2023-12-31 C001553 Intangible 2023-01-01 2023-12-31 C001553 1574 SHENANDOAH SEWAGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 98 AVONDALE MILL ROAD, Distribution, Unattended 2023-12-31 C001553 99 AVONLEA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1156 MORGAN FALLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1823 TYSON FOODS (Cumming), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1864 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 Miscellaneous Transmission Substation Additions & Improvements 2023-01-01 2023-12-31 C001553 412 CRAWFISH CREEK, Transmission, Unattended 2023-12-31 C001553 Material Sale, Mississippi Power Company 2023-01-01 2023-12-31 C001553 Vacation Pay Accrued 2023-01-01 2023-12-31 C001553 1037 MAGNOLIA MANOR, Distribution, Unattended 2023-12-31 C001553 1388 POWER PARTNERS, Distribution, Unattended 2023-12-31 C001553 1472 RITE AID (Newnan), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaenous Transmission Line Replacements ferc:ElectricUtilityMember 2023-12-31 C001553 FORT STEWART 2023-01-01 2023-12-31 C001553 CBM Monitor Deployment ferc:ElectricUtilityMember 2023-12-31 C001553 Porsche Cars North America Inc, LU, 2023-01-01 2023-12-31 C001553 237 BUENA VISTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 196 BOWEN, Generation, Attended 2023-12-31 C001553 BOAT ROCK, ADAMSVILLE 230 KV LN, Steel Single Pole, 1033 ACSR 2023-01-01 2023-12-31 C001553 1617 SOUTH GAINESVILLE, Distribution, Unattended 2023-12-31 C001553 637 FORREST LAKE, Distribution, Unattended 2023-12-31 C001553 Nacoochee (A) 2023-12-31 C001553 1781 TOTAL SYSTEM SERVICES, Distribution, Unattended 2023-12-31 C001553 1998 WOODGRAIN MILLWORK, Distribution, Unattended 2023-12-31 C001553 1590 SMITHVILLE, Distribution, Unattended 2023-12-31 C001553 1349 PILGRIMS PRIDE #2 (Athens), Distribution, Unattended 2023-12-31 C001553 1192 NECO, Distribution, Unattended 2023-12-31 C001553 TOUSCFI Time of Use Supplier Choice FPO 2023-01-01 2023-12-31 C001553 721 GERDAU, Distribution, Unattended 2023-12-31 C001553 108 BARCO #1 (TALLAPOOSA) PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 931 KERRY #3 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 465 DEKALB COUNTY SEWAGE (Snapfinger Rd), Distribution, Unattended 2023-01-01 2023-12-31 C001553 2012 YAMAHA, Distribution, Unattended 2023-12-31 C001553 1492 ROBINS AFB #4 - W.D. Fowler, Distribution, Unattended 2023-12-31 C001553 Appling 1st Series 1997 - Variable 2023-12-31 C001553 485, BARTLETTS FERRY 2023-01-01 2023-12-31 C001553 139 BEN HILL, Distribution, Unattended 2023-12-31 C001553 945 KING SPRINGS ROAD, Distribution, Unattended 2023-12-31 C001553 Funding Collateral 2023-12-31 C001553 BONAIRE, NORTH TIFTON 230 KV LN, Steel H-Frame, 795 ACSR 2023-01-01 2023-12-31 C001553 1096 MCRAE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1424 PYRAMAX CERAMICS, Distribution, Unattended 2023-12-31 C001553 Tampa Electric Company, OS, T4 2023-01-01 2023-12-31 C001553 1100 MEDUSA PORTLAND CEMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Vacation Pay Accrued 2023-12-31 C001553 1813 TWIN LAKES, Transmission, Unattended 2023-12-31 C001553 Grid Investment ferc:ElectricUtilityMember 2023-12-31 C001553 1918 WARRENTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 489 DIXIE PIPELINE (Eatonton), Distribution, Unattended 2023-12-31 C001553 FICA-COVID 19 State, Payroll Tax, 0, 2022-12-31 C001553 Occupancy, Southern Company Services 2023-01-01 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 ferc:CurrentYearMember ferc:NitrogenOxideMember 2023-01-01 2023-12-31 C001553 156 BLACK BEAR PM, Distribution, Unattended 2023-12-31 C001553 1758 THOMASTON, Distribution, Unattended 2023-12-31 C001553 Plant Vogtle 1&2 - Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 1874 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 1398 PRESIDENT STREET SEWAGE, Distribution, Unattended 2023-12-31 C001553 Doraville Balance of Substation Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 195 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 584 EUHARLEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1411 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Green Power Solutions Inc2, LU, 2023-01-01 2023-12-31 C001553 1074 MCINTOSH, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1254 NOWHERE ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 AUGUSTA, NEWSPRINT 230 KV LOOP LN, Steel H-Frame, 1351 ACSR 2023-01-01 2023-12-31 C001553 1532 SAPA EXTRUDER, Distribution, Unattended 2023-12-31 C001553 354 COBLE DAIRY PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 854 IDEAL WOOD PELLETS PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Tennessee, 2023-12-31 C001553 ferc:DirectPayrollDistributionMember Other Non-Operating Expenses 2023-01-01 2023-12-31 C001553 399 COOSA, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember 2022-12-31 C001553 908 JOHNS CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1681 STATESBORO PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 835 HIRAM SUDIE PM Retired, Distribution, Unattended 2023-12-31 C001553 2006 WRENS PRIMARY, Distribution, Unattended 2023-12-31 C001553 676 GAINESVILLE #1, Transmission, Unattended 2023-12-31 C001553 679 GAINESVILLE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Hercules, LU, 2023-01-01 2023-12-31 C001553 671 FURYS FERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Vogtle 3&4 Construction 2023-01-01 2023-12-31 C001553 1794 TREUTLEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OperatingReserveSupplementMember 2023-01-01 2023-12-31 C001553 824 HERTY LABS, Distribution, Unattended 2023-12-31 C001553 1017 LOUISVILLE AREA #7 PM, Distribution, Unattended 2023-12-31 C001553 667 FRITO-LAY (Kathleen), Distribution, Unattended 2023-12-31 C001553 TOTAL COMPANY COST, 2023-01-01 2023-12-31 C001553 963 LAKE LANIER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1278 OLD RIVER ROAD PM, Distribution, Unattended 2023-12-31 C001553 OOSTANAULA-PINSON 230KV, 230, 11.41, 31480 2023-01-01 2023-12-31 C001553 500 KV STEEL STRUCTURES, , , 2023-01-01 2023-12-31 C001553 1048 MARION SPENCE ROAD PM, Distribution, Unattended 2023-12-31 C001553 766 GRESHAMVILLE PM (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:EnergyImbalanceMember 2023-01-01 2023-12-31 C001553 SAVANNAH RIVER PLT (SCEG) 2, 230, 3.99, 113031 2023-01-01 2023-12-31 C001553 497 DODD ROAD, Distribution, Unattended 2023-12-31 C001553 Stewart County 2023-01-01 2023-12-31 C001553 402 CORINTH ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 20230501-5592, 45047, ER10-203-000 2023-01-01 2023-12-31 C001553 280 CARROLLTON #2, Distribution, Unattended 2023-12-31 C001553 114 BARTLETTS FERRY, Transmission, Unattended 2023-12-31 C001553 Series 2007 A - 5.65% 2023-01-01 2023-12-31 C001553 72 ASHBURN PRIMARY, Distribution, Unattended 2023-12-31 C001553 , Advanced Energy Systems 506 2023-01-01 2023-12-31 C001553 1735 TEMPERANCE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1939 WEST DALLAS, Distribution, Unattended 2023-12-31 C001553 921 KAMIN MINE (Thomson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 174 BOBBY JONES, Distribution, Unattended 2023-12-31 C001553 687 GEORGE ANDREWS LOCK & DAM PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 382 COMMODORE PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 764 GREENVILLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2012 - Variable 2023-12-31 C001553 1210 NORTH DRUID HILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Facility ferc:ElectricUtilityMember 2023-12-31 C001553 1847 VALLEY HILL ROAD, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Plant Hatch - Miscellaneous Additions 2023-12-31 C001553 17 ALADDIN FIBER ONE #2 PD, Distribution, Unattended 2023-12-31 C001553 930 KERRY #2 PD, Distribution, Unattended 2023-12-31 C001553 1902 WALLACE DAM, Generation, Attended 2023-01-01 2023-12-31 C001553 1061 MARTIN MARIETTA (Warrenton), Distribution, Unattended 2023-12-31 C001553 Series 2010B - 5.4% 2023-12-31 C001553 1303 PACTIV #6, Distribution, Unattended 2023-12-31 C001553 724 GILMAN PAPER (Fitzgerald), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1539 SCHERER COMMON FACILITIES, Generation, Attended 2023-12-31 C001553 Burke 5th Series 1995 - 2.20% 2023-01-01 2023-12-31 C001553 Midwest Independent Trans System OS 2023-01-01 2023-12-31 C001553 474 DEPTFORD, Transmission, Unattended 2023-12-31 C001553 870 ISSAC HALL PM, Distribution, Unattended 2023-12-31 C001553 1240 NORTH VALDOSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1550 SCHERER UNIT 2, Generation, Attended 2023-01-01 2023-12-31 C001553 SOUTH GRIFFIN 230 KV LN, 230, 0.01, 0 2023-01-01 2023-12-31 C001553 1989 WINDWARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SAWNEE EMC v. GPC - DOCKET NO. 2023-01-01 2023-12-31 C001553 MAS Georgia LFG LLC2, LU, 2023-01-01 2023-12-31 C001553 RTPDSCH Real Time Pricing Day Ahead - School Service 2023-01-01 2023-12-31 C001553 444 DAVIE SLICE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 681 GAINESVILLE WATER WORKS #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1899 WALKER CO. INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 371 2023-01-01 2023-12-31 C001553 Accounts Receivable ferc:DirectPayrollDistributionMember 2023-01-01 2023-12-31 C001553 1298 PACKAGING CORPORATION (Macon), Distribution, Unattended 2023-12-31 C001553 2354, YONAH 2023-01-01 2023-12-31 C001553 1777 TODD MARSHALL PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1569 SHAW INDUSTRIES #2 PD (Trenton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 940 KIMBALL BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WINDER 230 KV LN, 230, 6.63, 25150 2023-01-01 2023-12-31 C001553 DOCKET ITEMS UNDER $25,000 (7 2023-01-01 2023-12-31 C001553 OL_NGRE Outdoor Lighting 2023-01-01 2023-12-31 C001553 1359 PLAINS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2354, TALLULAH FALLS 2023-12-31 C001553 896 JEFFERSONVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 291 CEDAR SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1988 WINDWARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2413, WALLACE DAM 2023-12-31 C001553 517 DUBLIN, Distribution, Unattended 2023-12-31 C001553 882 JACK MCDONOUGH CC #4, Generation, Attended 2023-01-01 2023-12-31 C001553 MOR FALL-NO MARIETTA 230 KV, 230, 25.36, 181550 2023-01-01 2023-12-31 C001553 199 BOWEN, Generation, Attended 2023-12-31 C001553 EATONTON 230 KV LN, 230, 15.63, 211421 2023-01-01 2023-12-31 C001553 1188 NASHVILLE #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1690 STONE MOUNTAIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Flint River (B) 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Dawson Crossing-S Dahlonega 500kv T/L 2023-01-01 2023-12-31 C001553 BOWEN, TVA 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 409 COTTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 1457 REMLERS CORNER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1659 SPALDING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1895 W. S. CATRETT PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1583 SINCLAIR DAM HYDRO, Generation, Attended 2023-12-31 C001553 1799 TRIPPS BEACH PM, Distribution, Unattended 2023-12-31 C001553 106 BALDWIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1401 PROCTER & GAMBLE (Albany), Distribution, Unattended 2023-12-31 C001553 788 HAMILTON ROAD, Distribution, Unattended 2023-12-31 C001553 809 HATCH, Generation, Attended 2023-12-31 C001553 1660 SPALDING DRIVE, Distribution, Unattended 2023-12-31 C001553 1647 SOUTHERN NATURAL GAS (Ellerslie), Distribution, Unattended 2023-01-01 2023-12-31 C001553 2024 ZIPPER, Distribution, Unattended 2023-12-31 C001553 ferc:OtherLicenseAndFeesTaxMember 2022-12-31 C001553 1806 TUCKER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1068 MCDONOUGH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 545 EAST VIDALIA, Distribution, Unattended 2023-12-31 C001553 318 CHINA HILL ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 876 J. T. RYERSON & SON #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PowerSouth Energy Cooperative, OS, T4 2023-01-01 2023-12-31 C001553 866 INTERSTATE PAPER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Business License, Other License And Fees Tax, Mississippi, 2023-12-31 C001553 1912 WARRENTON, Distribution, Unattended 2023-12-31 C001553 886 JACK MCDONOUGH CC #5, Generation, Attended 2023-01-01 2023-12-31 C001553 Balancing Operating Reserve 2023-01-01 2023-03-31 C001553 APS-COM Agricultural Process Service 2023-01-01 2023-12-31 C001553 1034 MAGNOLIA BLUFF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 480 DIAMOND HILL AREA PM, Distribution, Unattended 2023-12-31 C001553 112 BARTLETTS FERRY, Transmission, Unattended 2023-12-31 C001553 1229 NORTH ROCKMART, Distribution, Unattended 2023-12-31 C001553 Piedmont Green Power, LU, 2023-01-01 2023-12-31 C001553 DOE Loan 3.283% - 2044 2023-12-31 C001553 ferc:IncomeTaxMember 2023-01-01 2023-12-31 C001553 97 AUTREY FURNITURE, Distribution, Unattended 2023-12-31 C001553 782 GWINNETT COUNTY WFP (Shoal Creek), Distribution, Unattended 2023-12-31 C001553 1655 SOUTHWEST DUBLIN, Distribution, Unattended 2023-12-31 C001553 1285 ORANGE, Distribution, Unattended 2023-12-31 C001553 561 ELLAVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1277 OLD NATIONAL, Distribution, Unattended 2023-12-31 C001553 Other Basis Differences - 109 ferc:ElectricUtilityMember 2023-12-31 C001553 Transmission Solar Interconnection (c) 2023-12-31 C001553 1113 METTER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1505 ROPER INDUSTRIES (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 204 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1503 ROOPVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Underground Addition & Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Business License, Other License And Fees Tax, Alabama, 2023-01-01 2023-12-31 C001553 MCINTOSH COAL 230 KV LN, 230, 0, 0 2023-01-01 2023-12-31 C001553 1087 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 Reserve for Future Capital Spend ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1452 REIDSVILLE, Distribution, Unattended 2023-12-31 C001553 337 CLOUDLAND CANYON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 645 FORT BENNING, Transmission, Unattended 2023-12-31 C001553 1218 NORTH JEFFERSON, Distribution, Unattended 2023-12-31 C001553 922 KAOLIN, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1626 SOUTH NORCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1202 NORMAN PARK ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 OFFERMAN 230KV LN, , , 0 2023-01-01 2023-12-31 C001553 MCCONNENELL ROAD 230KV, 230, 8.52, 0 2023-01-01 2023-12-31 C001553 220 BROADWAY, Distribution, Unattended 2023-12-31 C001553 74 ATHENA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1118 MILLEDGEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1520 SAINT MARYS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Flint EMC, LU, T4 2023-01-01 2023-12-31 C001553 1412 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 840 HOMERVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Tenaska Heard County Georgia, LU, 2023-01-01 2023-12-31 C001553 232 BRUNSWICK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WALLACE DAM HYDRO RE- 2023-01-01 2023-12-31 C001553 357 COCHRAN PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ALABAMA STATE LINE 230 KV L, 230, 8.42, 10253 2023-01-01 2023-12-31 C001553 1679 STATESBORO PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1134 MILLIKEN (Pine Mountain), Distribution, Unattended 2023-01-01 2023-12-31 C001553 2002 WRENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1903 WALMART, Distribution, Unattended 2023-12-31 C001553 Other Income and Deductions 2023-01-01 2023-12-31 C001553 458 DEARING, Distribution, Unattended 2023-12-31 C001553 1700 SUNDANCE PRODUCTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE 3 & 4 CONSTRUCTION 2023-12-31 C001553 1183 MULLITE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1896 WABASH, Distribution, Unattended 2023-12-31 C001553 997 LITHONIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 358 CODY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NitrogenOxideMember 2022-12-31 C001553 Other Post-Retirement Benefits and Pension-Associated Co 2022-12-31 C001553 1395 PREFERRED COMPOUNDING #2 PM, Distribution, Unattended 2023-12-31 C001553 772 GROVETOWN PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1544 SCHERER FGD 3/4, Generation, Attended 2023-01-01 2023-12-31 C001553 1264 OCHLOCKNEE, Distribution, Unattended 2023-12-31 C001553 1502 ROME, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1097 MEADOWS LAKE #1 PM, Distribution, Unattended 2023-12-31 C001553 1786 TRANSCO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 123 BAXLEY, Distribution, Unattended 2023-12-31 C001553 1500 ROGERS LANDING PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1437 RAY MOUNTAIN PM, Distribution, Unattended 2023-12-31 C001553 87 ATTAPULGUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Bartow 2nd Series 2009 2023-12-31 C001553 1622 SOUTH MACON, Distribution, Unattended 2023-12-31 C001553 Plant Bowen - Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 777 GULFSTREAM HANGAR, Distribution, Unattended 2023-12-31 C001553 GS- I General Service 2023-01-01 2023-12-31 C001553 1268 OCONEE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1797 TRINITY INDUSTRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Post-Retirement Benefits and Pension-Associated Co 2023-12-31 C001553 Georgia Power Company 2023-01-01 2023-12-31 C001553 1828 U.S. POSTAL FACILITY (Hapeville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 141 BERCKMAN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1458 RENESSENZ, Distribution, Unattended 2023-12-31 C001553 Other *ferc:ElectricUtilityMember 2023-12-31 C001553 1739 TENNECO AUTOMOTIVE, Distribution, Unattended 2023-12-31 C001553 SUTA, Payroll Tax, Georgia, 2023-12-31 C001553 1661 SPALDING DRIVE, Distribution, Unattended 2023-12-31 C001553 1951 WEYERHAEUSER (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Bartow 2nd Series 2009 2023-12-31 C001553 1729 TANYARD CREEK PM, Distribution, Unattended 2023-12-31 C001553 RTHPLSI RTP Hour Ahead/PLS-IND 2023-01-01 2023-12-31 C001553 687 GEORGE ANDREWS LOCK & DAM PM, Distribution, Unattended 2023-12-31 C001553 Heard 1st Series 2007 - Variable 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Transformer Replacement 2023-01-01 2023-12-31 C001553 104 BAKERS FERRY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 890 JACK MCDONOUGH CC #6, Generation, Attended 2023-01-01 2023-12-31 C001553 1572 SHAW INDUSTRIES (Thomson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 462 DECATUR COUNTY INDUSTRIAL, Distribution, Unattended 2023-12-31 C001553 1822 TYSON FOODS (Cumming), Distribution, Unattended 2023-12-31 C001553 1125 MILLHAVEN ANNEX, Transmission, Unattended 2023-12-31 C001553 Associated Energy Cooperative Inc., OS, T4 2023-01-01 2023-12-31 C001553 332 CLAXTON, Transmission, Unattended 2023-12-31 C001553 1682 STATHAM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 799 HARTSFIELD JACKSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Franchise Fees - 2023, Franchise Tax, Georgia, 2022-12-31 C001553 852 HUSQVARNA, Distribution, Unattended 2023-12-31 C001553 1658 SPALDING, Distribution, Unattended 2023-12-31 C001553 1303 PACTIV #6, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PLS-I Power & Light - Small 2023-01-01 2023-12-31 C001553 1913 WARRENTON AREA #1 PM, Distribution, Unattended 2023-12-31 C001553 BOWEN, UNION CITY #2 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 892 JACKSON COUNTY SENIOR CITIZENS PM, Distribution, Unattended 2023-12-31 C001553 802 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 797 HARTSFIELD FIFTH RUNWAY BRIDGE, Distribution, Unattended 2023-12-31 C001553 825 HIGHTOWER, Distribution, Unattended 2023-12-31 C001553 1055 MARTIN MARIETTA (Camak), Distribution, Unattended 2023-01-01 2023-12-31 C001553 VARIOUS Short Term Firm Customers VARIOUS Short Term Firm Customers VARIOUS SFP VARIOUS 0 2023-01-01 2023-12-31 C001553 CEDAR VILLAGE-ROYAL ATL 230, 230, 9.55, 907592 2023-01-01 2023-12-31 C001553 Fixed Assets 2022-01-01 2022-12-31 C001553 Spare Equipment Stock 2023-01-01 2023-12-31 C001553 1085 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 134 BELL, Distribution, Unattended 2023-12-31 C001553 Southern Company Services, Inc.Tariff Volume No. 13 , ER20-1735-002 2023-01-01 2023-12-31 C001553 1951, SINCLAIR DAM 2023-12-31 C001553 1901 WALLACE DAM, Generation, Attended 2023-01-01 2023-12-31 C001553 1086 MCMANUS, Generation, Attended 2023-12-31 C001553 1609 SOUTH AUGUSTA, Transmission, Unattended 2023-12-31 C001553 785 HAIRSTON ROAD, Distribution, Unattended 2023-12-31 C001553 1649 SOUTHERN NATURAL GAS (Fairburn), Distribution, Unattended 2023-12-31 C001553 701 GEORGIA PACIFIC (Durand), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1077 MCINTOSH CC, Generation, Attended 2023-01-01 2023-12-31 C001553 598 FAYETTEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1698 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1051 MARK GLASS PM, Distribution, Unattended 2023-12-31 C001553 1357 PITTMAN ROAD, Distribution, Unattended 2023-12-31 C001553 ROBINS AIR FORCE - DOCKET 2023-01-01 2023-12-31 C001553 401 COOSAWATTEE, Transmission, Unattended 2023-12-31 C001553 966 LAKE RIDGE PARKWAY, Distribution, Unattended 2023-12-31 C001553 1325 PEACHTREE, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Tennessee, 2023-12-31 C001553 KLONDIKE, 230, 0.4, 5667 2023-01-01 2023-12-31 C001553 1510 ROSWELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1421 PULASKI SEWAGE PM, Distribution, Unattended 2023-12-31 C001553 83 ATLANTA WATER WORKS (Adamsville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 567 ELLIJAY PRIMARY, Transmission, Unattended 2023-12-31 C001553 Santa Rosa, OS, T5 2023-01-01 2023-12-31 C001553 1561 SCOVILLE MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2023-01-01 2023-12-31 C001553 SC Public Service Authority OS 2023-01-01 2023-12-31 C001553 1031 MADRAS, Distribution, Unattended 2023-12-31 C001553 744 GOSSEN, Distribution, Unattended 2023-12-31 C001553 391 CONTAINER CORPORATION OF AMERICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 821 HERCULES (Savannah), Distribution, Unattended 2023-12-31 C001553 1976 WILSON, Generation, Attended 2023-12-31 C001553 1747 THALMANN STATION SERVICE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1639 SOUTHEASTERN REG RES LAB, Distribution, Unattended 2023-12-31 C001553 1715 SWEETWATER PAPER BOARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 21 ALADDIN FIBER ONE #8 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1531 SAPA EXTRUDER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1680 STATESBORO PRIMARY, Distribution, Unattended 2023-12-31 C001553 1089 MCMANUS, Generation, Attended 2023-12-31 C001553 209 BOWMAN, Distribution, Unattended 2023-12-31 C001553 67 ARMUCHEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 369 COLONIAL PIPELINE (Danielsville), Distribution, Unattended 2023-12-31 C001553 1145 MOLENA #2 PM, Distribution, Unattended 2023-12-31 C001553 818 HAZLEHURST WOOD PELLETS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 308 CHEROKEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 CWIP Electric ferc:NonUtilityMember 2023-01-01 2023-12-31 C001553 3 ABCD FARMS PM, Distribution, Unattended 2023-12-31 C001553 Southern Electric Generating Co. (4th Issuance)ferc:CaptialStockMember 2023-12-31 C001553 999 LITHONIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2002 WRENS, Distribution, Unattended 2023-12-31 C001553 1507 ROSSIGNOL HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Motor Vehicle Tag Fees, Other Taxes and Fees, 0, 2023-01-01 2023-12-31 C001553 1601 SOLO CUP #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Christopher C. Womack, Chairman, President and CEO 2023-01-01 2023-12-31 C001553 1903 WALMART, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1591 SMITHVILLE, Distribution, Unattended 2023-12-31 C001553 231 BROWN FARM ROAD, Distribution, Unattended 2023-12-31 C001553 1161 MORGANVILLE, Distribution, Unattended 2023-12-31 C001553 407 CORPORATE RIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 295 CELANESE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 690 GEORGIA BAPTIST VILLAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 404 CORNELIA, Distribution, Unattended 2023-12-31 C001553 872 J. M. HUBER (Commerce), Distribution, Unattended 2023-12-31 C001553 992 LINDBERGH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 871 J. C. PENNEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1809 TURPIN HILL, Distribution, Unattended 2023-12-31 C001553 1542 SCHERER FGD 3/4, Generation, Attended 2023-12-31 C001553 1200 NORDIC COLD STORAGE (Doraville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 311 CHEROKEE ROAD, Transmission, Unattended 2023-12-31 C001553 1598 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1500 ROGERS LANDING PM, Distribution, Unattended 2023-12-31 C001553 1314 PARKENSON CHURCH ROAD PM, Distribution, Unattended 2023-12-31 C001553 1047 MARBLE VALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Ferc Relicensing Various Hydro Plants ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 533 EAST DAWSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 386 CONCORD GROVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1616 SOUTH EFFINGHAM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Retiree Benefit Plans 2022-12-31 C001553 1468 RIDGEWAY CHURCH ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1066 MCCREE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 113 BARTLETTS FERRY, Transmission, Unattended 2023-12-31 C001553 492 DIXIE PIPELINE (Norwood), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1705 SUWANEE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 959 LAGRANGE, Distribution, Unattended 2023-12-31 C001553 2013 YATES 6&7, Generation, Attended 2023-01-01 2023-12-31 C001553 TOU-PEV Time-of-Use - Plug In Electric Vehicle 2023-01-01 2023-12-31 C001553 1365 PLANTATION PIPELINE (Neese), Distribution, Unattended 2023-12-31 C001553 FARLEY, NORTH TIFTON 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 202 BOWEN, Generation, Attended 2023-12-31 C001553 919 KAMIN (Wrens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Transmission Line Hwy Change ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Solar ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 194 BOWEN, Generation, Attended 2023-12-31 C001553 982 LESLIE, Distribution, Unattended 2023-12-31 C001553 FUTA, Payroll Tax, 0,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 298 CERTAINTEED (Athens), Distribution, Unattended 2023-12-31 C001553 1423 PUTNAM PM, Distribution, Unattended 2023-12-31 C001553 1477 RIVERDALE, Distribution, Unattended 2023-12-31 C001553 Fran Forehand 2023-01-01 2023-12-31 C001553 1267 OCMULGEE STREET, Distribution, Unattended 2023-12-31 C001553 95 AUSTELL BOX BOARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 349 COBB MARIETTA WATER (Lower Roswell), Distribution, Unattended 2023-12-31 C001553 776 GULFSTREAM #3, Distribution, Unattended 2023-12-31 C001553 1442 REAL DEALS, Distribution, Unattended 2023-12-31 C001553 1840 UNIVERSITY OF GEORGIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 264 CALHOUN ROAD, Distribution, Unattended 2023-12-31 C001553 Utoy Springs Substation Site 2023-01-01 2023-12-31 C001553 Miscellaneous Deferred Credits 2023-12-31 C001553 ferc:AllocationOfPayrollChargedForClearingAccountsMember 2023-01-01 2023-12-31 C001553 371 COLONIAL PIPELINE (Smyrna), Distribution, Unattended 2023-12-31 C001553 491 DIXIE PIPELINE (Milner), Distribution, Unattended 2023-12-31 C001553 1948 WEST MOULTRIE, Distribution, Unattended 2023-12-31 C001553 1081 MCINTOSH CT, Generation, Attended 2023-12-31 C001553 1355 PINSON, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, South Carolina, 2023-12-31 C001553 460 DECATUR, Distribution, Unattended 2023-12-31 C001553 872 J. M. HUBER (Commerce), Distribution, Unattended 2023-01-01 2023-12-31 C001553 120 BATH, Distribution, Unattended 2023-12-31 C001553 Funding Collateral 2023-01-01 2023-12-31 C001553 436 DAHLONEGA PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1347 PILGRIMS PRIDE #1 (Athens), Distribution, Unattended 2023-12-31 C001553 412 CRAWFISH CREEK, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1335 PENN CAMP ROAD PM, Distribution, Unattended 2023-12-31 C001553 540 EAST POINT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 EAF-IND Electric Arc Furnace 2023-01-01 2023-12-31 C001553 302 CHADBOURN GOTHAM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1905 WALTHOURVILLE, Distribution, Unattended 2023-12-31 C001553 986 LIBERTY, Distribution, Unattended 2023-12-31 C001553 1243 NORTHPARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 377 COLUMBUS SEWAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 10%ferc:ElectricUtilityMember 2022-12-31 C001553 1912 WARRENTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1858 VIENNA PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 PLM-I Power & Light - Medium 2023-01-01 2023-12-31 C001553 2023-01-01 2023-06-30 C001553 392 2023-01-01 2023-12-31 C001553 379 COMER PRIMARY, Distribution, Unattended 2023-12-31 C001553 199 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1111 METTER, Distribution, Unattended 2023-12-31 C001553 452 DAWSON INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1032 MAGNOLIA, Transmission, Unattended 2023-12-31 C001553 846 HUB JUNCTION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1432 RAGLAND STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1740 TENNILLE CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1861 VINSON ROAD, Distribution, Unattended 2023-12-31 C001553 545 EAST VIDALIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2023, Property Tax, Georgia, 2023-01-01 2023-12-31 C001553 1872 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 344 COBB COUNTY R. L. SUTTON WRF, Distribution, Unattended 2023-12-31 C001553 2011 YAMAHA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Customer Service Operations Cyber Security 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember South Hall - Winder T/L 2023-12-31 C001553 1640 SOUTHERN BELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 39 ALTO, Distribution, Unattended 2023-12-31 C001553 909 JOHNS MANVILLE INTERNATIONAL, Distribution, Unattended 2023-12-31 C001553 1469 RINGGOLD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 167 BLOOMINGDALE, Distribution, Unattended 2023-12-31 C001553 1481 RIVERVIEW HYDRO, Generation, Attended 2023-12-31 C001553 747 GRADY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1274 OLD DALTON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Basis Differences - 109 ferc:ElectricUtilityMember 2022-12-31 C001553 1907 WANSLEY, Generation, Attended 2023-01-01 2023-12-31 C001553 David E. Slovensky 2023-01-01 2023-12-31 C001553 1898 WACO, Distribution, Unattended 2023-12-31 C001553 Plant Bowen - Air ferc:ElectricUtilityMember 2023-12-31 C001553 Monroe 1st Series 2008 - Variable 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, South Carolina,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Various 2023-12-31 C001553 2354, TALLULAH FALLS 2023-01-01 2023-12-31 C001553 1374 POOLER, Distribution, Unattended 2023-12-31 C001553 1141 MODULAR CONTAINER SYSTEMS, Distribution, Unattended 2023-12-31 C001553 900 JERED BROWN BROTHERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1194 NEW RIVERSIDE OCHRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 715 GEORGIA TECH RESEARCH (Cobb), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1079 MCINTOSH CT, Generation, Attended 2023-12-31 C001553 1810 TWILIGHT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2015 YATES 6&7, Generation, Attended 2023-01-01 2023-12-31 C001553 986 LIBERTY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 423 CRYSTAL LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1206 NORTH COLUMBUS, Distribution, Unattended 2023-12-31 C001553 OL-UN Outdoor Lighting 2023-01-01 2023-12-31 C001553 1749 THE ROCK, Distribution, Unattended 2023-12-31 C001553 343 COBB, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1692 STONEY BROOK PM, Distribution, Unattended 2023-12-31 C001553 ferc:PropertyTaxMember 2022-12-31 C001553 1994 WINTERTHUR, Distribution, Unattended 2023-12-31 C001553 Unassigned 2023-01-01 2023-12-31 C001553 1724 TALLULAH FALLS, Generation, Attended 2023-12-31 C001553 YATES, BONAIRE, Wood H-Frame, 1033 ACSR 2023-01-01 2023-12-31 C001553 750 GRAHAM PACKAGING #5 PD, Distribution, Unattended 2023-12-31 C001553 1001 LITTLE NEW YORK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1043 MANCHESTER, Distribution, Unattended 2023-12-31 C001553 1720 TALLASSEE ROAD SCHOOL PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 461 DECATUR COUNTY INDUSTRIAL, Distribution, Unattended 2023-12-31 C001553 944 KING SPRINGS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 A. ELECTRIC UTILITY R,D&D PERFORMED INTERNALLY, 2023-01-01 2023-12-31 C001553 958 LAFARGE AGGREGATES #4 PD Oxford, Distribution, Unattended 2023-01-01 2023-12-31 C001553 601 FAYETTEVILLE ROAD, Distribution, Unattended 2023-12-31 C001553 973 LAKEWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Deferred Affiliate Taxes Payable 2023-01-01 2023-12-31 C001553 1369 POMONA, Distribution, Unattended 2023-12-31 C001553 Appling First Series 2011 - Variable 2023-12-31 C001553 249 BURKHALTER ROAD, Distribution, Unattended 2023-12-31 C001553 493 DIXIE PIPELINE (Putney), Distribution, Unattended 2023-12-31 C001553 544 EAST VIDALIA, Distribution, Unattended 2023-12-31 C001553 1587 SKIDAWAY ISLAND, Distribution, Unattended 2023-12-31 C001553 105 BALDWIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 89 AUGUSTA AREA #4 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 923 KAOLIN, Transmission, Unattended 2023-12-31 C001553 S Dahlonega-Clermont Jct 230kv T/L 2023-01-01 2023-12-31 C001553 24 ALADDIN MILLS #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 1997 - Variable 2023-01-01 2023-12-31 C001553 304 CHATHAM COUNTY INDUSTRIAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Rincon Solar I, LLC, LU, 2023-01-01 2023-12-31 C001553 1149 MONROE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Bowen - Air ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:AugustMember Georgia Power Company 2023-01-01 2023-12-31 C001553 712 GEORGIA STATE PATROL - FAA BEACON PM, Distribution, Unattended 2023-12-31 C001553 680 GAINESVILLE WATER WORKS, Distribution, Unattended 2023-12-31 C001553 501 DONALSONVILLE, Distribution, Unattended 2023-12-31 C001553 707 GEORGIA PACIFIC GYPSUM (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1425 QUACCO ROAD, Distribution, Unattended 2023-12-31 C001553 2017 YATES COMMON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:CaptialStockMember 2023-01-01 2023-12-31 C001553 Series 2019B - 2.65% 2023-12-31 C001553 DOE Loan 2.537% - 2044 2023-01-01 2023-12-31 C001553 1642 SOUTHERN LNG, Distribution, Unattended 2023-12-31 C001553 0 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2012 - Variable 2023-01-01 2023-12-31 C001553 Nuclear 2023-01-01 2023-12-31 C001553 KING'S BAY 2023-01-01 2023-12-31 C001553 1060 MARTIN MARIETTA (Tyrone), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Alabama,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1315 PARKWAY, Distribution, Unattended 2023-12-31 C001553 965 LAKE OCONEE, Distribution, Unattended 2023-12-31 C001553 267 CAMP ODOM PM, Distribution, Unattended 2023-12-31 C001553 674 GAILLARD PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 574 ENGELHARD (Savannah), Distribution, Unattended 2023-12-31 C001553 1553 SCHERER UNIT 3, Generation, Attended 2023-12-31 C001553 1550 SCHERER UNIT 2, Generation, Attended 2023-12-31 C001553 (A) Licensed Project Number 2354. 2023-01-01 2023-12-31 C001553 Seminole Electric Cooperative, OS, T4 2023-01-01 2023-12-31 C001553 1375 PORTER PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 HATCH SAT 2E SERVICE 230KV LINE, 230, 0.19, 0 2023-01-01 2023-12-31 C001553 190 BOULEVARD (Atlanta), Transmission, Unattended 2023-12-31 C001553 Plant Hatch - Mechanical 2023-01-01 2023-12-31 C001553 484 DITTLER BROTHERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Solar 2023-01-01 2023-12-31 C001553 3%ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Series 2012A - 4.30% 2023-12-31 C001553 761 GREENS MILL ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 71 ASHBURN PRIMARY, Distribution, Unattended 2023-12-31 C001553 1025 M&M MARS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 General Shops Expenses 2023-01-01 2023-12-31 C001553 1078 MCINTOSH CT, Generation, Attended 2023-12-31 C001553 275 CARLTON RURAL PM, Distribution, Unattended 2023-12-31 C001553 1537 SAULTER PM, Distribution, Unattended 2023-12-31 C001553 Outdoor Lighting Projects 2023-01-01 2023-12-31 C001553 1391 PPG INDUSTRIES, Distribution, Unattended 2023-12-31 C001553 1030 MADRAS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1450 REIDS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1909 WANSLEY PUMPING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 South Hall - Winder T/L 2023-01-01 2023-12-31 C001553 976 LANZATECH, Distribution, Unattended 2023-12-31 C001553 Tool Clearing 2023-01-01 2023-12-31 C001553 972 LAKEWOOD, Distribution, Unattended 2023-12-31 C001553 Accounting, Finance, Treasury, Southern Company Services 2023-01-01 2023-12-31 C001553 Transmission Line Hwy Change ferc:ElectricUtilityMember 2023-12-31 C001553 499 DODGE EASTMAN INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 1239 NORTH VALDOSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Environmental Remediation 2022-12-31 C001553 1384 POULAN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 146 BEULAH PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1198 NIPPER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 845 HOWARD #2 PM, Distribution, Unattended 2023-12-31 C001553 1993 WINN DIXIE (Atlanta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Macquarie Energy, LLC, OS, 2023-01-01 2023-12-31 C001553 348 COBB MARIETTA WATER (Allatoona), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Richland Solar Center LLC, LU, 2023-01-01 2023-12-31 C001553 1441 RAYONIER (Jesup), Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember Wallace Dam - Klondike 500 KV 2023-01-01 2023-12-31 C001553 975 LANGBOARD (Quitman), Distribution, Unattended 2023-01-01 2023-12-31 C001553 376 COLUMBUS FOUNDRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1654 SOUTHERN WOOD SUPPLIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 9 AERO COMMANDER, Distribution, Unattended 2023-12-31 C001553 1366 PLANTATION PIPELINE (Subligna), Distribution, Unattended 2023-12-31 C001553 485, BARTLETTS FERRY 2023-12-31 C001553 1333 PELHAM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Generation Software Upgrades 2023-01-01 2023-12-31 C001553 568 ELLIJAY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Building Additions & Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 1984 WINCHESTER SUBDIVISION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 NORCROSS 230 KV LN, 230, 7.52, 438478 2023-01-01 2023-12-31 C001553 1706 SUWANEE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 239 BUFFALO ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1245 NORTHSIDE DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 3.213% - 2044 2023-12-31 C001553 363 COLONELS ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 549 EASTMAN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 427 CULVERTON #3 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 210 BOXWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 659 FORTY FIFTH STREET, Distribution, Unattended 2023-12-31 C001553 , Environmental Controls Technologies 506 2023-01-01 2023-12-31 C001553 34 ALLATOONA HEIGHTS PM, Distribution, Unattended 2023-12-31 C001553 65 ARMSTRONG GLASS (Jasper), Distribution, Unattended 2023-12-31 C001553 1135 MILLIRONS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 236 BUDWEISER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 488 DIXIE PIPELINE (Appling), Distribution, Unattended 2023-12-31 C001553 1111 METTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1174 MOUNTAIN SPRINGS #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1883 VOGTLE 3&4 500KV, Generation, Attended 2023-01-01 2023-12-31 C001553 STATESBORO 230 KV (SAV), 230, 21.87, 0 2023-01-01 2023-12-31 C001553 0 2023-01-01 2023-12-31 C001553 1465 RICE CREEK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1478 RIVERDALE, Distribution, Unattended 2023-12-31 C001553 1221 NORTH MACON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1441 RAYONIER (Jesup), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1639 SOUTHEASTERN REG RES LAB, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Nuclear Engineering Operating Services, Southern Nuclear Operating Company 2023-01-01 2023-12-31 C001553 375 COLUMBUS FOUNDRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1927 WAYNE FARMS, Distribution, Unattended 2023-12-31 C001553 227 BROWN AND WILLIAMSON TOBACCO, Distribution, Unattended 2023-12-31 C001553 902 JESUP CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 54 ANTIOCH ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1407 PROPEX #11 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 542 EAST VALDOSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 377 COLUMBUS SEWAGE, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (BLACK) 230 KV (SA, 230, 8.23, 0 2023-01-01 2023-12-31 C001553 124 BAXLEY, Distribution, Unattended 2023-12-31 C001553 Asset Retirement Obligations 2022-12-31 C001553 G-C Governmental 2023-01-01 2023-12-31 C001553 Southern Company Transmission, OS, 2023-01-01 2023-12-31 C001553 509 DOUBLE CHURCHES ROAD, Distribution, Unattended 2023-12-31 C001553 Tennessee Valley Authority Tennessee Valley Authority Distributors of Tennessee Valley Authority FNO N/A 1517 2023-01-01 2023-12-31 C001553 504 DORAVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Medical Arts Substation Site 2023-01-01 2023-12-31 C001553 518 DULUTH, Distribution, Unattended 2023-12-31 C001553 1563 SEALY PM, Distribution, Unattended 2023-12-31 C001553 Estimated Loss on Plant Vogtle Units 3 and 4 2022-01-01 2022-12-31 C001553 1840 UNIVERSITY OF GEORGIA, Distribution, Unattended 2023-12-31 C001553 35 ALLEN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1179 MRS. SMITHS BAKERIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 198 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 Series 2010B - 5.4% 2023-01-01 2023-12-31 C001553 Plant McIntosh - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 378 COLUMBUS SQUARE, Distribution, Unattended 2023-12-31 C001553 1907 WANSLEY, Generation, Attended 2023-12-31 C001553 Common Stock (all owned by Southern Company) 2023-01-01 2023-12-31 C001553 1292 OWENS ILLINOIS (Hamilton Boulevard), Distribution, Unattended 2023-01-01 2023-12-31 C001553 516 DUBLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Reserve for Future Capital Spend ferc:ElectricUtilityMember 2023-12-31 C001553 1383 POULAN, Distribution, Unattended 2023-12-31 C001553 Energy Efficiency Improvements 2022-12-31 C001553 Origis Energy, LU, 2023-01-01 2023-12-31 C001553 1797 TRINITY INDUSTRIES, Distribution, Unattended 2023-12-31 C001553 2000 WOODVALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Hatch - Controls ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Bartow 1st Series 2009 - 2.75% 2023-01-01 2023-12-31 C001553 Software & Cloud Computing 2023-01-01 2023-12-31 C001553 1225 NORTH MILLEDGEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1847 VALLEY HILL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 381 COMMERCE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1353 PINE GROVE PRIMARY, Transmission, Unattended 2023-12-31 C001553 Nuclear Financing 2023-01-01 2023-12-31 C001553 72 ASHBURN PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 327 CLARKESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Bowen - Clean Air Compliance ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Southern Company Services, OS, RS-138 2023-01-01 2023-12-31 C001553 ferc:SulfurDioxideMember ferc:CurrentYearMember 2022-12-31 C001553 FICA, Payroll Tax, 0, 2023-01-01 2023-12-31 C001553 1507 ROSSIGNOL HILL, Distribution, Unattended 2023-12-31 C001553 1013 LONG CANE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Northwest Region Operating HQ Site 2023-01-01 2023-12-31 C001553 708 GEORGIA PACIFIC SAWMILL (Albany), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Nuclear Engineering Maintenance Services, Southern Nuclear Operating Company 2023-01-01 2023-12-31 C001553 Series 2010C - 4.75% 2023-12-31 C001553 Other *ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1475 RIVER ROAD, Distribution, Unattended 2023-12-31 C001553 666 FREDERICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1699 SUMNER, Distribution, Unattended 2023-12-31 C001553 Midwest Independent Trans System, OS, 2023-01-01 2023-12-31 C001553 Burke 1st Series 2018 - Variable 2023-12-31 C001553 51 ANTHONY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1262 OAKEY WOODS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Technology ferc:ElectricUtilityMember 2023-12-31 C001553 GS-R General Service 2023-01-01 2023-12-31 C001553 1ST AVE COLUMBUS #2 230 KV , 230, 9.74, 48243 2023-01-01 2023-12-31 C001553 372 COLOR IMAGE, Distribution, Unattended 2023-12-31 C001553 575 ENGINEERED FABRICS, Distribution, Unattended 2023-12-31 C001553 CWIP Electric ferc:NonUtilityMember 2022-12-31 C001553 Revenue Erosion 2023-01-01 2023-12-31 C001553 ferc:GeneralPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 TOU-HLF Time of Use - High Load Factor 2023-01-01 2023-12-31 C001553 KING'S BAY 2023-12-31 C001553 1428 QUAIL RIDGE PM, Distribution, Unattended 2023-12-31 C001553 RTDRN-I RTP Day Ahead - Revenue Neutral 2023-01-01 2023-12-31 C001553 ferc:OperatingUtilityMember 2023-12-31 C001553 895 JEFFERSONVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 382 COMMODORE PARK, Distribution, Unattended 2023-12-31 C001553 546 EAST VIENNA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 250 BURNT HICKORY, Distribution, Unattended 2023-12-31 C001553 246 BULL MOOSE TUBE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1496 ROCHELLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1980 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 1243 NORTHPARK, Distribution, Unattended 2023-12-31 C001553 851 HUSQVARNA, Distribution, Unattended 2023-12-31 C001553 258 BUTLER STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 7%ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 779 GUTHRIE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 TC-M Traffic Control Metered 2023-01-01 2023-12-31 C001553 1357 PITTMAN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WALLACE DAM HYDRO RE- 2023-12-31 C001553 1578 SHURLING DRIVE, Distribution, Unattended 2023-12-31 C001553 884 JACK MCDONOUGH CC #5, Generation, Attended 2023-01-01 2023-12-31 C001553 1959 WHITEOAK, Transmission, Unattended 2023-12-31 C001553 1762 THOMSON AREA #8 PD, Distribution, Unattended 2023-12-31 C001553 934 KEYSTONE MEMORIALS, Distribution, Unattended 2023-12-31 C001553 1826 U.S. MARINE CORPS SUPPLY DEPOT, Distribution, Unattended 2023-12-31 C001553 Monroe 2nd Series 2009 - Variable 2023-01-01 2023-12-31 C001553 Burke 5th Series 1995 - 2.20% 2023-12-31 C001553 SAWNEE EMC v. GPC - DOCKET NO. 2023-12-31 C001553 1089 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 WARNER ROBINS 2023-12-31 C001553 Southern Electric Generating Co. (4th Issuance)ferc:CaptialStockMember 2023-01-01 2023-12-31 C001553 1564 SEARS FASHION CENTER 25/4 KV, Distribution, Unattended 2023-12-31 C001553 1683 STEEPLECHASE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WANSLEY SCRUBBER 230 KV TIE , 230, 2, 0 2023-01-01 2023-12-31 C001553 1514 ROYSTON, Distribution, Unattended 2023-12-31 C001553 90 AUGUSTA CORPORATE PARK, Distribution, Unattended 2023-12-31 C001553 1260 OAK STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 269 CANDLER HOSPITAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 109 BARNESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 608 FIELDALE FARMS (Cornelia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, South Carolina, 2022-12-31 C001553 1931 WELLS ALUMINUM #2 PM, Distribution, Unattended 2023-12-31 C001553 692 GEORGIA BOARD OF CORRECTIONS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1843 UPS DATA CENTER (Alpharetta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1405 PROPEX #1 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 MCMANUS 3 & 4 2023-12-31 C001553 485 DIVIDEND ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 910 JOHNS MANVILLE INTERNATIONAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1275 OLD HICKORY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 192 BOWDON JUNCTION PM, Distribution, Unattended 2023-12-31 C001553 OL-NGRE Outdoor Lighting 2023-01-01 2023-12-31 C001553 700 GEORGIA PACIFIC (Brunswick), Distribution, Unattended 2023-12-31 C001553 Software & Cloud Computing 2022-12-31 C001553 1346 PHILEMA ROAD, Distribution, Unattended 2023-12-31 C001553 1345 PHARMATECH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1259 OAK GROVE, Distribution, Unattended 2023-12-31 C001553 Franchise Fees - 2022, Franchise Tax, Georgia, 2023-01-01 2023-12-31 C001553 41 AMERICUS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1635 SOUTHEAST TOYOTA, Distribution, Unattended 2023-12-31 C001553 385 CONCORD GROVE, Distribution, Unattended 2023-12-31 C001553 1908 WANSLEY FGD, Generation, Attended 2023-01-01 2023-12-31 C001553 278 CARPENTER FLAT, Distribution, Unattended 2023-12-31 C001553 1454 REMERTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 262 CALHOUN COUNTY PRISON #1 PD (East), Distribution, Unattended 2023-01-01 2023-12-31 C001553 461 DECATUR COUNTY INDUSTRIAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 483 DILLARD PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 970 LAKELAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1674 STATE HIGHWAY TESTING LAB, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1490 ROBINS AFB #3, Distribution, Unattended 2023-12-31 C001553 1508 ROSSIGNOL HILL, Distribution, Unattended 2023-12-31 C001553 Series 2022B - 5.125% 2023-01-01 2023-12-31 C001553 931 KERRY #3 PD, Distribution, Unattended 2023-12-31 C001553 1340 PETERSBURG ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1261 OAK STREET, Distribution, Unattended 2023-12-31 C001553 274 CARL FINDLEY PM, Distribution, Unattended 2023-12-31 C001553 1416 PROPEX #7 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 TOUEO-I Time-of-Use - Energy Only 2023-01-01 2023-12-31 C001553 61 ARBOR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember Software Purchases and Upgrades 2023-12-31 C001553 PowerSouth Energy Cooperative PowerSouth Energy Cooperative PowerSouth Energy Cooperative FNO N/A 712 2023-01-01 2023-12-31 C001553 Verizon Communications, OS, 2023-01-01 2023-12-31 C001553 667 FRITO-LAY (Kathleen), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1707 SWAINSBORO AREA #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Green Energy, OS, 2023-01-01 2023-12-31 C001553 1634 SOUTH VILLA RICA, Distribution, Unattended 2023-12-31 C001553 1671 STANDRIDGE COLOR #18 PM, Distribution, Unattended 2023-12-31 C001553 1460 REST HAVEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1123 MILLEN PRIMARY, Transmission, Unattended 2023-12-31 C001553 364 COLONIAL PIPELINE (Armuchee), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1475 RIVER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 893 JAMES SHORT PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 736 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1595 SOCIAL CIRCLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 935 KIA MOTORS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1782 TOTO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1009 LOCKEBY PM, Distribution, Unattended 2023-12-31 C001553 1945 WEST END, Distribution, Unattended 2023-12-31 C001553 926 KEITH WHITE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ALABAMA STATE LINE 230 KV L, 230, 23.38, 28469 2023-01-01 2023-12-31 C001553 1932 WELLS ALUMINUM #2 PM, Distribution, Unattended 2023-12-31 C001553 Intangible ferc:ElectricUtilityMember 2023-12-31 C001553 425 CSX TRANSPORTATION PM (Fitzgerald), Distribution, Unattended 2023-12-31 C001553 651 FORT GORDON, Distribution, Unattended 2023-12-31 C001553 964 LAKE OCONEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:AprilMember 2023-01-01 2023-12-31 C001553 0, 0 2023-01-01 2023-12-31 C001553 OCEE, 230, 30.61, 586475 2023-01-01 2023-12-31 C001553 1868 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 1835 UNION POINT PRIMARY, Transmission, Unattended 2023-12-31 C001553 1608 SOUTH AUGUSTA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 888 JACK MCDONOUGH CC #6, Generation, Attended 2023-01-01 2023-12-31 C001553 1661 SPALDING DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1605 SOPERTON PRIMARY, Distribution, Unattended 2023-12-31 C001553 1785 TRANQUILLA HILL, Distribution, Unattended 2023-12-31 C001553 1604 SOLVAY ADVANCED POLYMERS, Distribution, Unattended 2023-12-31 C001553 398 COOPER TOOLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Scherer - Outage Projects 2023-01-01 2023-12-31 C001553 641 FORREST ROAD (Macon), Distribution, Unattended 2023-12-31 C001553 1422 PURCELL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 896 JEFFERSONVILLE, Distribution, Unattended 2023-12-31 C001553 527 EAST ATHENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1062 MARVIN GRIFFIN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 System Operations - Study Driven - Generation Changes ferc:ElectricUtilityMember 2023-12-31 C001553 916 JUNCTION CITY MINING PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 870 ISSAC HALL PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 984 LEWIS SIGN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1044 MANN ROAD PM, Distribution, Unattended 2023-12-31 C001553 1861 VINSON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 775 GULFSTREAM #2, Distribution, Unattended 2023-12-31 C001553 1269 OGLETHORPE MALL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1603 SOLO CUP #1, Distribution, Unattended 2023-12-31 C001553 815 HAWTHORNE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 823 HERRINGTON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 CBM Monitor Deployment ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1603 SOLO CUP #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Piedmont Substation Site 2023-01-01 2023-12-31 C001553 899 JENNINGS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1621 SOUTH MACON, Distribution, Unattended 2023-12-31 C001553 1257 NUTRASWEET, Distribution, Unattended 2023-12-31 C001553 Deferred Income Taxes 2022-12-31 C001553 1249 NORTHWEST PERRY, Distribution, Unattended 2023-12-31 C001553 ROBINS AFB 2023-01-01 2023-12-31 C001553 1674 STATE HIGHWAY TESTING LAB, Distribution, Unattended 2023-12-31 C001553 1201 NORDIC COLD STORAGE (Hapeville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:NovemberMember 2023-01-01 2023-12-31 C001553 1943 WEST DICKEY PM, Distribution, Unattended 2023-12-31 C001553 Asset Retirement Obligations 2023-01-01 2023-12-31 C001553 602 FEDERAL PENITENTIARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 356 COCHRAN PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Deferred Plant Retirement Costs 2023-12-31 C001553 1354 PINE MOUNTAIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FLA POWER & LIGHT 230 KV LN, 230, 4.18, 156797 2023-01-01 2023-12-31 C001553 219 BROAD RIVER STONE, Distribution, Unattended 2023-12-31 C001553 Southern Power Company, LU, 2023-01-01 2023-12-31 C001553 1140 MITCHELL 115, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Deferred Affiliate Taxes Payable 2022-12-31 C001553 (1) GENERATION, 2023-01-01 2023-12-31 C001553 Plant Hatch - Electrical ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Accounts Receivable 2023-01-01 2023-12-31 C001553 885 JACK MCDONOUGH CC #5, Generation, Attended 2023-01-01 2023-12-31 C001553 1425 QUACCO ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1457 REMLERS CORNER, Distribution, Unattended 2023-12-31 C001553 Printing and Reproduction 2023-01-01 2023-12-31 C001553 1943 WEST DICKEY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 4% 2023-01-01 2023-12-31 C001553 58 AQUILLA, Distribution, Unattended 2023-12-31 C001553 244 BULK FABRICATED PRODUCTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Customer Service System (CSS) Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 Business License, Other License And Fees Tax, Mississippi,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 357 2023-01-01 2023-12-31 C001553 477 DEVEREUX, Distribution, Unattended 2023-12-31 C001553 1112 METTER AREA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1602 SOLO CUP #1, Distribution, Unattended 2023-12-31 C001553 New Hampstead Substation 2023-01-01 2023-12-31 C001553 1730 TARA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Non-Operating Expenses ferc:AllocationOfPayrollChargedForClearingAccountsMember 2023-01-01 2023-12-31 C001553 0 2022-01-01 2022-12-31 C001553 399 COOSA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 80 ATLANTA WATER STORAGE (Lois Street), Distribution, Unattended 2023-01-01 2023-12-31 C001553 978 LAWRENCEVILLE HIGHWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 0 ferc:ElectricUtilityMember 2022-12-31 C001553 1568 SHARON PD, Distribution, Unattended 2023-12-31 C001553 173 BOBBY JONES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1324 PEACH ORCHARD, Distribution, Unattended 2023-12-31 C001553 GPC Vogtle 3&4 Construction Payments 2022-12-31 C001553 Shantella E. Cooper 2023-01-01 2023-12-31 C001553 ferc:OtherLicenseAndFeesTaxMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 936 KIA MOTORS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Short-Term Borrowings 2023-01-01 2023-12-31 C001553 1033 MAGNOLIA, Transmission, Unattended 2023-12-31 C001553 New Business 2023-01-01 2023-12-31 C001553 1047 MARBLE VALLEY, Distribution, Unattended 2023-12-31 C001553 265 CAMP JOSEY, Transmission, Unattended 2023-12-31 C001553 755 GRAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1002 LITTLE RIVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 881 JACK MCDONOUGH CC #4, Generation, Attended 2023-01-01 2023-12-31 C001553 1167 MOULTRIE, Distribution, Unattended 2023-12-31 C001553 Heard 1st Series 1996 - Variable 2023-12-31 C001553 397 2023-01-01 2023-12-31 C001553 BREMEN 230 KV LN, 230, 51.94, 6206445 2023-01-01 2023-12-31 C001553 843 HORSELEG CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 OLNG-BB Outdoor Lighting 2023-01-01 2023-12-31 C001553 234 BUCKHEAD PRIMARY, Distribution, Unattended 2023-12-31 C001553 1626 SOUTH NORCROSS, Distribution, Unattended 2023-12-31 C001553 1129 MILLIKEN (Lagrange), Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Tennessee,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1346 PHILEMA ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1166 MOULTRIE, Distribution, Unattended 2023-12-31 C001553 PEACHTREE-BLVD DC 230 KV LN, 230, 12.58, 43454758 2023-01-01 2023-12-31 C001553 1394 PREFERRED COMPOUNDING #1 PD, Distribution, Unattended 2023-12-31 C001553 726 GLYNDALE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1540 SCHERER CONSTRUCTION, Distribution, Attended 2023-12-31 C001553 6 ADAIRSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 City of Tallahassee, Florida, OS, 2023-01-01 2023-12-31 C001553 Southern Company Services (Self-Use) OS 2023-01-01 2023-12-31 C001553 1362 PLANTATION PIPELINE (Bremen), Distribution, Unattended 2023-12-31 C001553 990 LINDALE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1112 METTER AREA #2 PM, Distribution, Unattended 2023-12-31 C001553 1445 RED TOP MOUNTAIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 54 ANTIOCH ROAD, Distribution, Unattended 2023-12-31 C001553 36 ALPHARETTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OtherUtilityMember 2023-01-01 2023-12-31 C001553 1005 LLOYD SHOALS, Transmission, Attended 2023-01-01 2023-12-31 C001553 1273 OLD ALABAMA ROAD, Distribution, Unattended 2023-12-31 C001553 55 APAC (Camak), Distribution, Unattended 2023-12-31 C001553 Other 2022-01-01 2022-12-31 C001553 1046 MAR-JAC POULTRY #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 837 HOGANSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1637 SOUTHEAST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 Overstressed Or Obsolete Circuit Switcher Replacement 2023-01-01 2023-12-31 C001553 640 FORREST ROAD (Columbus), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ELLIJAY 230 KV LN, 230, 7.62, 0 2023-01-01 2023-12-31 C001553 1474 RIVER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 53 ANTIOCH ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 580 ERICK CHURCH ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MIDDLE FORK 230 KV LN, 230, 26.98, 8801408 2023-01-01 2023-12-31 C001553 RTHRN-I RTP Hour Ahead - Revenue Neutral 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, South Carolina,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 474 DEPTFORD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 670 FURNACE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Retiree Benefit Plans 2022-12-31 C001553 1886 VULCAN MATERIALS (Lithia Springs), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember S Dahlonega-Clermont Jct 500kv T/L 2023-01-01 2023-12-31 C001553 ferc:IncomeTaxMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 JACKSONVILLE ELECTRIC AUTHORITY JACKSONVILLE ELECTRIC AUTHORITY JEA LFP VOGTLE 61 2023-01-01 2023-12-31 C001553 1492 ROBINS AFB #4 - W.D. Fowler, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1580 SILK HOPE, Distribution, Unattended 2023-12-31 C001553 1566 SEVENTH AVENUE, Distribution, Unattended 2023-12-31 C001553 339 CLOVERLEAF, Distribution, Unattended 2023-12-31 C001553 419 CROSSGATE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 503 DORAVILLE, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (WHITE) 230 KV (SA, 230, 16.25, 0 2023-01-01 2023-12-31 C001553 1695 SUMMER LAKE, Distribution, Unattended 2023-12-31 C001553 Renewable Generation Collateral 2023-12-31 C001553 ALABAMA 230 KV LN, 230, 11.15, 125833 2023-01-01 2023-12-31 C001553 DOE Loan 1.652% - 2044 2023-01-01 2023-12-31 C001553 1731 TARVER, Transmission, Unattended 2023-12-31 C001553 1109 MERIWETHER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 (C) Approximately 1928. Record of Owners inadeq. 2023-01-01 2023-12-31 C001553 847 HUDSON WIRE, Distribution, Unattended 2023-12-31 C001553 1389 POWER PARTNERS, Distribution, Unattended 2023-12-31 C001553 1859 VILLA RICA PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1944 WEST DUBLIN, Distribution, Unattended 2023-12-31 C001553 1330 PEARSON, Distribution, Unattended 2023-12-31 C001553 VARIOUS Non Firm Customers VARIOUS Non Firm Customers VARIOUS NF VARIOUS 0 2023-01-01 2023-12-31 C001553 1950 WEYERHAEUSER (Colbert), Distribution, Unattended 2023-12-31 C001553 1361 PLANTATION PIPELINE (Austell), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other (provide details in footnote): 2022-01-01 2022-12-31 C001553 383 COMOLLI GRANITE, Distribution, Unattended 2023-12-31 C001553 622 FLAV-O-RICH IRVINDALE DAIRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1584 SIX MILE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PURRYSBURG (SPSCA) 230 KV (, 230, 1.98, 0 2023-01-01 2023-12-31 C001553 1050 MARK GLASS PM, Distribution, Unattended 2023-12-31 C001553 Municipal Electric Authority Of Georgia, OS, T4 2023-01-01 2023-12-31 C001553 200 BOWEN, Generation, Attended 2023-12-31 C001553 840 HOMERVILLE, Distribution, Unattended 2023-12-31 C001553 147 BIBB MANUFACTURING (Percale), Distribution, Unattended 2023-01-01 2023-12-31 C001553 861 INTERFOR (Baxley), Distribution, Unattended 2023-12-31 C001553 70 ASAMA COLDWATER MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 (1) RESEARCH SUPPORT TO THE ELECTRIC, 2023-01-01 2023-12-31 C001553 570 EMORY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 869 INTRENCHMENT CREEK SEWAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1342 PETTIT CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 26 ALADDIN MILLS #3, Distribution, Unattended 2023-12-31 C001553 1551 SCHERER UNIT 3, Generation, Attended 2023-01-01 2023-12-31 C001553 1288 ORCHARD HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OtherUtilityMember 2022-12-31 C001553 289 CEDAR CREEK ROAD PM, Distribution, Unattended 2023-12-31 C001553 1025 M&M MARS, Distribution, Unattended 2023-12-31 C001553 1038 MAGNOLIA PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 IOP-C Irrigation Off-Peak 2023-01-01 2023-12-31 C001553 1414 PROPEX #5 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 695 GEORGIA MARBLE #4 (Talking Rock), Distribution, Unattended 2023-12-31 C001553 1495 ROCHELLE, Distribution, Unattended 2023-12-31 C001553 1296 PACKAGING CORPORATION (Clyattville), Distribution, Unattended 2023-12-31 C001553 1238 NORTH TIFTON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 529 EAST BAINBRIDGE, Distribution, Unattended 2023-12-31 C001553 ferc:CurrentYearMember ferc:NitrogenOxideMember 2022-12-31 C001553 569 EMORY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1200 NORDIC COLD STORAGE (Doraville), Distribution, Unattended 2023-12-31 C001553 Plant Bowen - Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1716 SWIFT SPINNING MILLS #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 953 KIRKWOOD, Distribution, Unattended 2023-12-31 C001553 1613 SOUTH COBB DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1285 ORANGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 464 DEKALB COUNTY SEWAGE (Snapfinger Rd), Distribution, Unattended 2023-01-01 2023-12-31 C001553 122 BAXLEY, Distribution, Unattended 2023-12-31 C001553 Contract Retention 2023-12-31 C001553 974 LANGBOARD (Quitman), Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 1.737% - 2044 2023-12-31 C001553 180 BOLTON, Distribution, Unattended 2023-12-31 C001553 346 COBB MARIETTA WATER #1 (Johnson Ferry), Distribution, Unattended 2023-01-01 2023-12-31 C001553 140 BENDIX FRICTION MATERIALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1019 LUCENT TECHNOLOGIES #1 (OFS FITEL), Distribution, Unattended 2023-12-31 C001553 1808 TUGALO, Generation, Attended 2023-12-31 C001553 380 COMER PRIMARY, Distribution, Unattended 2023-12-31 C001553 1802 TROUP CREEK, Distribution, Unattended 2023-12-31 C001553 Series N - 5.750% 2023-01-01 2023-12-31 C001553 1426 QUACCO ROAD, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, South Carolina, 2023-01-01 2023-12-31 C001553 23 ALADDIN MILLS #2, Distribution, Unattended 2023-12-31 C001553 731 GODFREY ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 651 FORT GORDON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1881 VOGTLE 3&4 500KV, Generation, Attended 2023-12-31 C001553 1443 REBECCA, Distribution, Unattended 2023-12-31 C001553 1915 WARRENTON AREA #3 PM, Distribution, Unattended 2023-12-31 C001553 366 COLONIAL PIPELINE (Bremen), Distribution, Unattended 2023-12-31 C001553 1256 NUTRASWEET, Distribution, Unattended 2023-12-31 C001553 1209 NORTH DRUID HILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1643 SOUTHERN LNG, Distribution, Unattended 2023-12-31 C001553 BOWEN NORTH 230 KV LN, , , 0 2023-01-01 2023-12-31 C001553 1322 PEACH ORCHARD, Distribution, Unattended 2023-12-31 C001553 496 DIXON LAKE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 87 ATTAPULGUS, Distribution, Unattended 2023-12-31 C001553 605 FIELDALE (Cornelia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 329 CLARKS BRIDGE, Distribution, Unattended 2023-12-31 C001553 416 CREEKWOOD SUBDIVISION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 16 ALADDIN FIBER ONE #1 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 423 CRYSTAL LAKE, Distribution, Unattended 2023-12-31 C001553 1180 MUD CREEK, Distribution, Unattended 2023-12-31 C001553 373 COLQUITT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1948 WEST MOULTRIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 703 GEORGIA PACIFIC (Monticello), Distribution, Unattended 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 Replace Failed Equipment ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Other Clearing Accounts ferc:DirectPayrollDistributionMember 2023-01-01 2023-12-31 C001553 817 HAZLEHURST PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1807 TUCKER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1165 MOULTRIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:GenerationStudiesMember None 2023-01-01 2023-12-31 C001553 1526 SALEM GATE, Distribution, Unattended 2023-12-31 C001553 Georgia Power Company Rate ScheduleFERC No. 835, ER02-1574-000 2023-01-01 2023-12-31 C001553 763 GREENVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 313 CHICKAMAUGA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 84 ATLANTA WATER WORKS (Moores Mill), Distribution, Unattended 2023-01-01 2023-12-31 C001553 647 FORT BENNING #2, Transmission, Unattended 2023-01-01 2023-12-31 C001553 252 BURTON HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 Plant Mcintosh - Outage Projects ferc:ElectricUtilityMember 2023-12-31 C001553 Southwest Power Pool, Inc, OS, T4 2023-01-01 2023-12-31 C001553 Business License, Other License And Fees Tax, Alabama, 2023-12-31 C001553 1220 NORTH KITE, Distribution, Unattended 2023-12-31 C001553 283 CASSVILLE, Distribution, Unattended 2023-12-31 C001553 346 COBB MARIETTA WATER #1 (Johnson Ferry), Distribution, Unattended 2023-12-31 C001553 1664 SPIVEY LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1914 WARRENTON AREA #2 PM, Distribution, Unattended 2023-12-31 C001553 Protective Relay Modernization Project ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 539 2023-01-01 2023-12-31 C001553 387 CONLEY CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 742 GOSHEN (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 158 BLACKSHEAR, Distribution, Unattended 2023-12-31 C001553 1464 RHINE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1515 ROYSTON, Distribution, Unattended 2023-12-31 C001553 2007 WRIGHTSBORO ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1350 PILGRIMS PRIDE #3 (Athens), Distribution, Unattended 2023-12-31 C001553 VOGTLE 3 & 4 CONSTRUCTION 2023-01-01 2023-12-31 C001553 187 BORAL BRICK, Distribution, Unattended 2023-12-31 C001553 384 CONCORD, Distribution, Unattended 2023-12-31 C001553 MCGRAU FORD 230 KV LN, 230, 18.5, 7158888 2023-01-01 2023-12-31 C001553 MCLB Albany (NAVFEC), LU, 2023-01-01 2023-12-31 C001553 121 BATTLECREEK, Distribution, Unattended 2023-12-31 C001553 1776 TODD MARSHALL PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FLORIDA POWER & LIGHT COMPANY EXELON GENERATION COMPANY, LLC GTC LFP SCHERER 215 2023-01-01 2023-12-31 C001553 927 KELLOGGS SNACKS, Distribution, Unattended 2023-12-31 C001553 1636 SOUTHEAST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 1651 SOUTHERN RAILWAY (Inman Yards), Distribution, Unattended 2023-12-31 C001553 656 FORT STEWART, Distribution, Unattended 2023-01-01 2023-12-31 C001553 501 DONALSONVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Vogtle 1&2 - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 PLM-R Power & Light - Medium 2023-01-01 2023-12-31 C001553 352 2023-01-01 2023-12-31 C001553 Miscellaneous Distribution Line Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 Net Worth, Other License And Fees Tax, Georgia, 2023-01-01 2023-12-31 C001553 420 CROSSROADS PARKWAY, Distribution, Unattended 2023-12-31 C001553 1962 WHITESTONE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1142 MOHAWK INDUSTRIES (East Dublin), Distribution, Unattended 2023-12-31 C001553 1736 TEMPLE, Distribution, Unattended 2023-12-31 C001553 1281 OLIVER DAM HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 TOU-MB Time of Use - Multiple Business 2023-01-01 2023-12-31 C001553 1341 PETERSON CREEK, Distribution, Unattended 2023-12-31 C001553 1270 OHOOPEE RIVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PORTERDALE, 230, 13.43, 190258 2023-01-01 2023-12-31 C001553 Burke 2nd Series 1994 - 2.25% 2023-01-01 2023-12-31 C001553 1150 MONROE INDUSTRIAL PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1799 TRIPPS BEACH PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BOWEN, PINSON, Steel H-Frame, 795 ACSR 2023-01-01 2023-12-31 C001553 2019 YONAH, Generation, Attended 2023-12-31 C001553 408 COTTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 865 INTERSTATE CENTRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 473 DEMOREST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Enterprise Solutions System Upgrades 2023-01-01 2023-12-31 C001553 Spare Equipment Stock ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 433 CYPRESS POINT, Distribution, Unattended 2023-12-31 C001553 Deferred Compensation 2022-12-31 C001553 336 CLERMONT JUNCTION, Distribution, Unattended 2023-12-31 C001553 1587 SKIDAWAY ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1747 THALMANN STATION SERVICE, Distribution, Unattended 2023-12-31 C001553 1777 TODD MARSHALL PM, Distribution, Unattended 2023-12-31 C001553 Renewable Generation Collateral 2023-01-01 2023-12-31 C001553 Communications Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 649 FORT GILLEM, Distribution, Unattended 2023-12-31 C001553 1214 NORTH HIGHLANDS, Generation, Attended 2023-12-31 C001553 1541 SCHERER FGD 1/2, Generation, Attended 2023-12-31 C001553 1397 PREFERRED COMPOUNDING #4 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Southern Electric Generating Co. (3rd Issuance)ferc:CaptialStockMember 2023-01-01 2023-12-31 C001553 350 COBB MARIETTA WATER (Wyckoff), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Spare Equipment Stock ferc:ElectricUtilityMember 2023-12-31 C001553 333 CLAYTON, Distribution, Unattended 2023-12-31 C001553 497 DODD ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Advanced Contribution for 2022-12-31 C001553 1795 TRI COUNTY FARMS PM, Distribution, Unattended 2023-12-31 C001553 1027 MABLETON, Distribution, Unattended 2023-12-31 C001553 1064 MCBEAN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 68 ARTESIAN STREET, Distribution, Unattended 2023-12-31 C001553 1317 PATRIOTS PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1581 SIMPSON LUMBER, Distribution, Unattended 2023-12-31 C001553 1360 PLANTATION PIPELINE PM (Bio), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1075 MCINTOSH CC, Generation, Attended 2023-12-31 C001553 1804 TRUMAN PARKWAY, Distribution, Unattended 2023-12-31 C001553 1641 SOUTHERN GATEWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other * 2023-01-01 2023-12-31 C001553 1012 LOCKHEED MARTIN WIND TUNNEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Tri-County EMC, LU, T4 2023-01-01 2023-12-31 C001553 1300 PACTIV #2, Distribution, Unattended 2023-12-31 C001553 2004 WRENS AREA #1 PM, Distribution, Unattended 2023-12-31 C001553 Energy Efficiency Improvements 2023-12-31 C001553 1309 PALMYRA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 12 AIRGAS (Pendergrass), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1290 OWENS BROCKWAY (Sylvan Road), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ROW Services Perfection 2023-01-01 2023-12-31 C001553 Power Delivery Support Services, Southern Company Services 2023-01-01 2023-12-31 C001553 Deferred Capitalized Interest on Nuclear 2023-12-31 C001553 247 BURGESS PIGMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1926 WAYCROSS MOULDED PRODUCTS, Distribution, Unattended 2023-12-31 C001553 1041 MAIN STREET #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1667 SPRING STREET, Distribution, Unattended 2023-12-31 C001553 PLANT VOGTLE, KLONDIKE 500KV LN, , 2023-01-01 2023-12-31 C001553 1729 TANYARD CREEK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FORT BENNING 2023-12-31 C001553 1197 NEWTON, Distribution, Unattended 2023-12-31 C001553 R Residential 2023-01-01 2023-12-31 C001553 1411 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1404 PROPEX #1 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 145 BETHLEHEM 115/25-KV, Distribution, Unattended 2023-12-31 C001553 1426 QUACCO ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Total Income Tax Payable 2023-01-01 2023-12-31 C001553 SCHERER 2023-01-01 2023-12-31 C001553 Retiree Benefit Plans 2023-01-01 2023-12-31 C001553 Customer Data Usage 2022-12-31 C001553 1339 PERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 928 KENNESAW, Distribution, Unattended 2023-12-31 C001553 CAC Contract, LU, 2023-01-01 2023-12-31 C001553 662 FOX TRACE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 961 LAKE JENNIFER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1999 WOODPECKER PM, Distribution, Unattended 2023-12-31 C001553 2018 YATES VILLAGE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1271 OLD ALABAMA ROAD, Distribution, Unattended 2023-12-31 C001553 1427 QUAIL HOLLOW PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 695 GEORGIA MARBLE #4 (Talking Rock), Distribution, Unattended 2023-01-01 2023-12-31 C001553 475 DERING CIRCLE 115, Distribution, Unattended 2023-01-01 2023-12-31 C001553 374 COLUMBUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2013 - Variable 2023-12-31 C001553 1485 ROBERTS ROAD, Distribution, Unattended 2023-12-31 C001553 Franchise Fees - 2022, Franchise Tax, Georgia, 2022-12-31 C001553 Disputed Payments 2023-12-31 C001553 SUTA, Payroll Tax, Georgia, 2022-12-31 C001553 489 DIXIE PIPELINE (Eatonton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 230 BROWN FARM ROAD, Distribution, Unattended 2023-12-31 C001553 910 JOHNS MANVILLE INTERNATIONAL, Distribution, Unattended 2023-12-31 C001553 1188 NASHVILLE #1, Distribution, Unattended 2023-12-31 C001553 394 COOLIDGE, Distribution, Unattended 2023-12-31 C001553 214 BRENTWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Misc GSU ferc:ElectricUtilityMember 2023-12-31 C001553 11 AIR PRODUCTS AND CHEMICALS, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Georgia, 2023-01-01 2023-12-31 C001553 McGrau Ford BESS Site 2023-01-01 2023-12-31 C001553 FLAT-GS Flat Bill - General Service 2023-01-01 2023-12-31 C001553 1769 TILLY MILL, Distribution, Unattended 2023-12-31 C001553 403 CORNELIA, Distribution, Unattended 2023-12-31 C001553 137 BELVEDERE, Distribution, Unattended 2023-12-31 C001553 830 HIGHWAY 515 PM (Ellijay), Distribution, Unattended 2023-01-01 2023-12-31 C001553 760 GREENBRIAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1548 SCHERER UNIT 1, Generation, Attended 2023-12-31 C001553 367 COLONIAL PIPELINE (Dacula), Distribution, Unattended 2023-01-01 2023-12-31 C001553 844 HOUSTON CHAPEL, Distribution, Unattended 2023-12-31 C001553 577 ERCO WORLDWIDE, Distribution, Unattended 2023-12-31 C001553 796 HARTFORD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1653 SOUTHERN WOOD SUPPLIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 125 BAYER CROPSCIENCE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:SulfurDioxideMember Adjustment 2023-01-01 2023-12-31 C001553 NORCROSS 230 KV LN, 230, 77.65, 473871 2023-01-01 2023-12-31 C001553 DOE Loan 1.737% - 2044 2023-01-01 2023-12-31 C001553 1534 SARGENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1102 MEDUSA PORTLAND CEMENT #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1559 SCOTTDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Underground Addition & Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 582 ETON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1373 POOLER, Distribution, Unattended 2023-12-31 C001553 1102 MEDUSA PORTLAND CEMENT #3, Distribution, Unattended 2023-12-31 C001553 117 BARTOW, Distribution, Unattended 2023-12-31 C001553 1940 WEST DALLAS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NitrogenOxideMember Adjustment 2023-01-01 2023-12-31 C001553 907 JOHNS CREEK, Distribution, Unattended 2023-12-31 C001553 Deferred Plant Retirement Costs 2022-12-31 C001553 836 HOBBS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2012A - 4.30% 2023-01-01 2023-12-31 C001553 1483 RIVERWOOD #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 657 FORT STEWART SOLAR (IC-385), Generation, Attended 2023-12-31 C001553 Fiber Optics Spurs Construction 2023-01-01 2023-12-31 C001553 1971 WILLINGHAM DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Power Delivery Software Upgrades 2023-01-01 2023-12-31 C001553 1069 MCDONOUGH, Distribution, Unattended 2023-12-31 C001553 Series 2023C - Variable 2023-01-01 2023-12-31 C001553 909 JOHNS MANVILLE INTERNATIONAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SOUTH ACWORTH 230 KV LN, 230, 15.07, 2875580 2023-01-01 2023-12-31 C001553 1906 WANSLEY, Generation, Attended 2023-12-31 C001553 1953 WHIRLWIND STEEL PD, Distribution, Unattended 2023-12-31 C001553 DSM Over Recovery 2023-01-01 2023-12-31 C001553 548 EASTANOLLEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 648 FORT GAINES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1509 ROSSMAN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 495 DIXIE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 South Carolina Public Service Authority, OS, 2023-01-01 2023-12-31 C001553 887 JACK MCDONOUGH CC #5, Generation, Attended 2023-12-31 C001553 618 FLAT CREEK, Distribution, Unattended 2023-12-31 C001553 607 FIELDALE FARMS #2 (Murrayville), Distribution, Unattended 2023-12-31 C001553 Burke 4th Series 1995 - 2.25% 2023-01-01 2023-12-31 C001553 1266 OCMULGEE STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 49 ANGLO AMERICAN CLAY TEMPORARY PM, Distribution, Unattended 2023-12-31 C001553 Burke 1st Series 1996 - Variable 2023-01-01 2023-12-31 C001553 526 EAST AMERICUS, Distribution, Unattended 2023-12-31 C001553 1386 POWDER SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 305 CHATSWORTH, Distribution, Unattended 2023-12-31 C001553 FICA, Payroll Tax, 0, 2023-12-31 C001553 ferc:DirectPayrollDistributionMember Printing and Reproduction 2023-01-01 2023-12-31 C001553 803 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 83 ATLANTA WATER WORKS (Adamsville), Distribution, Unattended 2023-12-31 C001553 1700 SUNDANCE PRODUCTS, Distribution, Unattended 2023-12-31 C001553 612 FIFTEENTH STREET, Transmission, Unattended 2023-12-31 C001553 Burke 3rd Series 2012 - Variable 2023-12-31 C001553 19 ALADDIN FIBER ONE #6 PD, Distribution, Unattended 2023-12-31 C001553 OL-UN Outdoor Lighting 2023-01-01 2023-12-31 C001553 EVANS 230 LINE, , , 0 2023-01-01 2023-12-31 C001553 1791 TRENTON, Distribution, Unattended 2023-12-31 C001553 1368 PLEASANTDALE ROAD, Distribution, Unattended 2023-12-31 C001553 23 ALADDIN MILLS #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1087 MCMANUS, Generation, Attended 2023-12-31 C001553 1466 RICHARDSON STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Outdoor Lighting Projects ferc:ElectricUtilityMember 2023-12-31 C001553 e. Unconventional Generation, Renewable, Storage, Distributed Generation 2023-01-01 2023-12-31 C001553 1199 NORDIC COLD STORAGE #2 (Doraville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2022A - 4.70% 2023-01-01 2023-12-31 C001553 1928 WAYNESBORO, Distribution, Unattended 2023-12-31 C001553 540 EAST POINT, Distribution, Unattended 2023-12-31 C001553 769 GRIFFIN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 262 CALHOUN COUNTY PRISON #1 PD (East), Distribution, Unattended 2023-12-31 C001553 Software Purchases and Upgrades 2023-01-01 2023-12-31 C001553 643 FORSTMANN (Louisville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 729 GOAT ROCK HYDRO, Generation, Attended 2023-12-31 C001553 762 GREENSBORO, Distribution, Unattended 2023-12-31 C001553 573 ENGELHARD (McIntyre), Distribution, Unattended 2023-01-01 2023-12-31 C001553 9 AERO COMMANDER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1024 M A INDUSTRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 905 JOHNS CREEK, Distribution, Unattended 2023-12-31 C001553 Printing Service, Southern Company Services 2023-01-01 2023-12-31 C001553 684 GARDEN CITY TERMINAL WEST, Distribution, Unattended 2023-12-31 C001553 1579 SILGAN PLASTICS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 442 DARIEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 44 AMHERST, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote): 2023-01-01 2023-12-31 C001553 155 BILL FRANKS PM, Distribution, Unattended 2023-12-31 C001553 1487 ROBINS AFB #1, Distribution, Unattended 2023-12-31 C001553 FORT VALLEY STATE UNIVERSITY 2023-01-01 2023-12-31 C001553 967 LAKE SINCLAIR, Distribution, Unattended 2023-12-31 C001553 HATCH, OFFERMAN-FLA ST LN 500 KV L, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 797 HARTSFIELD FIFTH RUNWAY BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1432 RAGLAND STREET, Distribution, Unattended 2023-12-31 C001553 WADLEY VIDALIA #2 230 KV LN, 230, 46.17, 11953 2023-01-01 2023-12-31 C001553 288 CDC (Clifton Road), Distribution, Unattended 2023-12-31 C001553 880 JACK MCDONOUGH, Generation, Attended 2023-12-31 C001553 709 GEORGIA PORTS AUTHORITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1760 THOMPSON BRIDGE, Distribution, Unattended 2023-12-31 C001553 1658 SPALDING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 650 FORT GILLEM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1021 LUDOWICI PRIMARY, Transmission, Unattended 2023-12-31 C001553 Series 2023B - 4.95% 2023-01-01 2023-12-31 C001553 Plant Hatch - Mechanical ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Pre pay 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Boyd Ave Substation Site 2023-01-01 2023-12-31 C001553 Solar ferc:ElectricUtilityMember 2023-12-31 C001553 Nuclear Administrative and Other Related Services, Southern Nuclear Operating Company 2023-01-01 2023-12-31 C001553 RTPHGSDI Real Time Pricing Hour Ahead - Time of Use - General Service Demand 2023-01-01 2023-12-31 C001553 801 HARTWELL SERIES REACTOR, Transmission, Unattended 2023-12-31 C001553 1080 MCINTOSH CT, Generation, Attended 2023-12-31 C001553 ferc:NitrogenOxideMember 2023-01-01 2023-12-31 C001553 1338 PERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 69 ASAMA COLDWATER MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1716 SWIFT SPINNING MILLS #2, Distribution, Unattended 2023-12-31 C001553 233 BUCKHEAD (Madison) (NEW), Distribution, Unattended 2023-12-31 C001553 2237, MORGAN FALLS 2023-12-31 C001553 33 ALKEN-ZEIGLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1021 LUDOWICI PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1300 PACTIV #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 253 BUTLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1542 SCHERER FGD 3/4, Generation, Attended 2023-01-01 2023-12-31 C001553 532 EAST CUTHBERT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1406 PROPEX #10 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Transmission Solar Interconnection (c) 2022-12-31 C001553 1858 VIENNA PRIMARY, Transmission, Unattended 2023-12-31 C001553 FSTOU-I Farm Service Time of Use 2023-01-01 2023-12-31 C001553 345 COBB COUNTY R. L. SUTTON WRF, Distribution, Unattended 2023-12-31 C001553 536 EAST EVANS, Distribution, Unattended 2023-12-31 C001553 649 FORT GILLEM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 222 BRODIE METER, Distribution, Unattended 2023-12-31 C001553 345 COBB COUNTY R. L. SUTTON WRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 457 DEAN STEEL BUILDINGS, Distribution, Unattended 2023-12-31 C001553 ferc:SulfurDioxideMember 2023-12-31 C001553 ferc:DirectPayrollDistributionMember Tool Clearing 2023-01-01 2023-12-31 C001553 336 CLERMONT JUNCTION, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Reliability ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Power Delivery Software Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Solar Glynn, LLC, LU, 2023-01-01 2023-12-31 C001553 1644 SOUTHERN MILLS #1 (Senoia), Distribution, Unattended 2023-12-31 C001553 1449 REFUGE ROAD PM, Distribution, Unattended 2023-12-31 C001553 906 JOHNS CREEK, Distribution, Unattended 2023-12-31 C001553 586 EVANS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 906 JOHNS CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Dominion Energy, OS, 2023-01-01 2023-12-31 C001553 Miscellaneous 2023-01-01 2023-06-30 C001553 970 LAKELAND, Distribution, Unattended 2023-12-31 C001553 296 CENTRAL AVENUE, Distribution, Unattended 2023-12-31 C001553 1194 NEW RIVERSIDE OCHRE, Distribution, Unattended 2023-12-31 C001553 1205 NORTH CLARKESVILLE, Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember Bethabara-E. Walton 230kv T/L Site 2023-12-31 C001553 453 DAWSON PRIMARY, Transmission, Unattended 2023-12-31 C001553 1467 RICHMOND HILL, Distribution, Unattended 2023-12-31 C001553 Southeastern Power Administration Southeastern Power Administration Southeastern Power Administration Preference Customers FNO N/A 379 2023-01-01 2023-12-31 C001553 Asset Retirement Obligations 2023-12-31 C001553 1358 PITTS CHAPEL ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Alabama, 2023-01-01 2023-12-31 C001553 1731 TARVER, Transmission, Unattended 2023-01-01 2023-12-31 C001553 314 CHICOPEE MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 730 GOAT ROCK HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 DEMAND SIDE MANAGEMENT CERTIFICATION - DOCKET NOS. 42311, 43040, and 44161 2023-12-31 C001553 1672 STANDRIDGE COLOR #2, Distribution, Unattended 2023-12-31 C001553 1510 ROSWELL, Distribution, Unattended 2023-12-31 C001553 Various 2023-01-01 2023-12-31 C001553 JOHNSON FY-DERING CIR, 230, 7.21, 547901 2023-01-01 2023-12-31 C001553 1543 SCHERER FGD 3/4, Generation, Attended 2023-01-01 2023-12-31 C001553 Burke 2nd Series 2012 - 1.70% 2023-01-01 2023-12-31 C001553 1388 POWER PARTNERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 538 EAST MACON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 6 ADAIRSVILLE, Distribution, Unattended 2023-12-31 C001553 848 HUDSON WIRE, Distribution, Unattended 2023-12-31 C001553 1680 STATESBORO PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 614 FIRST AVENUE, Transmission, Unattended 2023-12-31 C001553 2018 YATES VILLAGE PD, Distribution, Unattended 2023-12-31 C001553 300 CERTAINTEED (Social Circle), Distribution, Unattended 2023-12-31 C001553 473 DEMOREST, Distribution, Unattended 2023-12-31 C001553 FORT BENNING 2023-01-01 2023-12-31 C001553 48 ANGLO AMERICAN CLAY TEMPORARY PM, Distribution, Unattended 2023-12-31 C001553 Other General Plant 2023-01-01 2023-12-31 C001553 86 ATTAPULGUS, Distribution, Unattended 2023-12-31 C001553 1960 WHITEOAK, Transmission, Unattended 2023-12-31 C001553 Federal Income Taxes 2022 & Prior, Income Tax, , 2022-12-31 C001553 1568 SHARON PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1717 SYLVESTER PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 164 BLOOMFIELD, Distribution, Unattended 2023-12-31 C001553 786 HAIRSTON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 864 INTERSTATE CENTRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1736 TEMPLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OtherLicenseAndFeesTaxMember 2023-12-31 C001553 1932 WELLS ALUMINUM #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 610 FIFE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 City of Dalton, Dalton Utilities, LU, T4 2023-01-01 2023-12-31 C001553 75 ATHENS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 229 BROWN BROTHERS SAND PIT, Distribution, Unattended 2023-12-31 C001553 1315 PARKWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1518 RUSSELL AREA PM Retired, Distribution, Unattended 2023-12-31 C001553 823 HERRINGTON ROAD, Distribution, Unattended 2023-12-31 C001553 1462 RETTCO STEEL, Distribution, Unattended 2023-12-31 C001553 257 BUTLER STREET, Distribution, Unattended 2023-12-31 C001553 WEST MCINTOSH (WHITE) 230 K, 230, 0.4, 0 2023-01-01 2023-12-31 C001553 1448 REDMOND CIRCLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 110 BARNETT ROAD, Distribution, Unattended 2023-12-31 C001553 171 BOAT ROCK ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1895 W. S. CATRETT PM, Distribution, Unattended 2023-12-31 C001553 1140 MITCHELL 115, Transmission, Unattended 2023-12-31 C001553 Federal Income Taxes 2023, Income Tax, , 2022-12-31 C001553 E. WATKINSVILLE 230 KV LN, 230, 7.92, 298748 2023-01-01 2023-12-31 C001553 576 ENGLISHVILLE, Distribution, Unattended 2023-12-31 C001553 271 CANON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1190 NATIONAL BEEF, Distribution, Unattended 2023-12-31 C001553 1448 REDMOND CIRCLE, Distribution, Unattended 2023-12-31 C001553 496 DIXON LAKE PM, Distribution, Unattended 2023-12-31 C001553 ferc:OtherLicenseAndFeesTaxMember 2023-01-01 2023-12-31 C001553 1882 VOGTLE 3&4 500KV, Generation, Attended 2023-01-01 2023-12-31 C001553 1620 SOUTH GEORGIA METHODIST NURSING HOME, Distribution, Unattended 2023-01-01 2023-12-31 C001553 HATCH 2023-12-31 C001553 JACKSONVILLE ELECTRIC AUTHORITY JACKSONVILLE ELECTRIC AUTHORITY JEA LFP VOGTLE 42 2023-01-01 2023-12-31 C001553 216 BRIAR VISTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1204 NORTH AWRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2009 - 1.00% 2023-12-31 C001553 686 GEO SPECIALTY CHEMICAL (HENKEL), Distribution, Unattended 2023-12-31 C001553 572 ENGELHARD (Gordon), Distribution, Unattended 2023-12-31 C001553 206 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1935 WEST 11TH STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1592 SMYRNA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 642 FORREST ROAD (Macon), Distribution, Unattended 2023-12-31 C001553 1082 MCINTOSH CT, Generation, Attended 2023-01-01 2023-12-31 C001553 1280 OLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 626 FLINT RIVER PRIMARY, Transmission, Unattended 2023-12-31 C001553 1798 TRION, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1886 VULCAN MATERIALS (Lithia Springs), Distribution, Unattended 2023-12-31 C001553 Generating Plant Outage Costs 2023-01-01 2023-12-31 C001553 16 ALADDIN FIBER ONE #1 PD, Distribution, Unattended 2023-12-31 C001553 20 ALADDIN FIBER ONE #7 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company Rate Schedule No. 838 , ER24-457-000 2023-01-01 2023-12-31 C001553 390 CONSOLIDATED MINERALS PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 522 DUNCAN MILL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 109 BARNESVILLE, Distribution, Unattended 2023-12-31 C001553 554 EATONTON PUMPING PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1833 UNIMIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Retiree Benefit Plans 2023-01-01 2023-12-31 C001553 234 BUCKHEAD PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 857 INDUSTRIAL BOULEVARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Wallace Dam - Klondike 500 KV 2023-01-01 2023-12-31 C001553 Generation Software Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1483 RIVERWOOD #1 PM, Distribution, Unattended 2023-12-31 C001553 Supplemental Executive Retirement Plan (SERP), Alabama Power Company 2023-01-01 2023-12-31 C001553 Bulldog Solar, LLC, LU, 2023-01-01 2023-12-31 C001553 Communications Improvements 2023-01-01 2023-12-31 C001553 1113 METTER PRIMARY, Distribution, Unattended 2023-12-31 C001553 176 BOJO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 324 CHOKEE PLANTATION #2 PM, Distribution, Unattended 2023-12-31 C001553 827 HIGHWAY 106 PM (Commerce), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Southern Electric Generating Co. (3rd Issuance)ferc:CaptialStockMember 2023-12-31 C001553 1968 WILLIAMS CIRCLE SUBDIVISION PM, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (BLACK) 230 KV (SA, 230, 16.23, 260863 2023-01-01 2023-12-31 C001553 142 BERKELEY LAKE, Distribution, Unattended 2023-12-31 C001553 506 DOSTER ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1732 TATUM ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 355 COCA COLA (Hapeville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1575 SHENANDOAH SEWAGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 403 CORNELIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1299 PACTIV #2, Distribution, Unattended 2023-12-31 C001553 Load Related System Improvements 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Georgia, 2022-12-31 C001553 520 DUNCAN BRIDGE ROAD, Distribution, Unattended 2023-12-31 C001553 1651 SOUTHERN RAILWAY (Inman Yards), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1323 PEACH ORCHARD, Distribution, Unattended 2023-12-31 C001553 1686 STOCKBRIDGE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1264 OCHLOCKNEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2022-12-31 C001553 981 LEESBURG, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 3.283% - 2044 2023-01-01 2023-12-31 C001553 211 BOYD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 621 FLAT SHOALS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 860 INLAND ROME, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MOR FALL-NO MARIETTA 230 KV, 230, 1.14, 8161 2023-01-01 2023-12-31 C001553 TOUSC-C Time of Use Supplier Choice 2023-01-01 2023-12-31 C001553 1916 WARRENTON AREA #5 PM, Distribution, Unattended 2023-12-31 C001553 1832 UNILEVER, Distribution, Unattended 2023-12-31 C001553 1234 NORTH THOMASTON, Distribution, Unattended 2023-12-31 C001553 Southwest Power Pool, Inc, OS, 2023-01-01 2023-12-31 C001553 Floriday Power & Light Company OS 2023-01-01 2023-12-31 C001553 1244 NORTHPARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burton (A) 2023-12-31 C001553 UC Unmetered Communication 2023-01-01 2023-12-31 C001553 1766 THRALL CAR MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 1876 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 1217 NORTH JEFFERSON, Distribution, Unattended 2023-12-31 C001553 789 HANSON AGGREGATES (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1095 MCPHERSON MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 Washington County Pwr, OS, 2023-01-01 2023-12-31 C001553 Duke Energy Carolinas, LLC, OS, 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Transformer Replacement ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1885 VULCAN MATERIALS (Grayson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 366 2023-01-01 2023-12-31 C001553 1577 SHURLING DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1768 TIFTON PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1770 TIMBERMEN #1 (Warrenton), Distribution, Unattended 2023-12-31 C001553 1280 OLIN, Distribution, Unattended 2023-12-31 C001553 1820 TYCO PLASTICS #12 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SCOTTDALE-BLVD 230 KV LN, 230, 13.29, 364041 2023-01-01 2023-12-31 C001553 407 CORPORATE RIDGE, Distribution, Unattended 2023-12-31 C001553 1030 MADRAS, Distribution, Unattended 2023-12-31 C001553 1498 ROCKMART, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1656 SOUTHWIRE, Distribution, Unattended 2023-12-31 C001553 283 CASSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1123 MILLEN PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 543 EAST VALDOSTA, Distribution, Unattended 2023-12-31 C001553 Plant Vogtle Units 3&4 Construction 2023-01-01 2023-12-31 C001553 Technology ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 292 CEDAR SPRINGS, Distribution, Unattended 2023-12-31 C001553 1994 WINTERTHUR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 619 FLAT CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-12-31 C001553 39 ALTO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 626 FLINT RIVER PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 190 BOULEVARD (Atlanta), Transmission, Unattended 2023-01-01 2023-12-31 C001553 Plant Mcintosh - Outage Projects ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 397 COOPER TOOLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1570 SHAW INDUSTRIES (Milledgeville), Distribution, Unattended 2023-12-31 C001553 240 BUFFALO ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1525 SALE CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 676 GAINESVILLE #1, Transmission, Unattended 2023-01-01 2023-12-31 C001553 329 CLARKS BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2008 - Variable 2023-12-31 C001553 Short-Term Borrowings 2022-01-01 2022-12-31 C001553 1251 NORTHWEST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 Solar Design & Development LLC, OS, 2023-01-01 2023-12-31 C001553 2023 ZEBULON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Supply Chain Management, Southern Company Services 2023-01-01 2023-12-31 C001553 614 FIRST AVENUE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 10%ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 159 BLACKSMITH, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1627 SOUTH NORCROSS, Distribution, Unattended 2023-12-31 C001553 1970 WILLINGHAM DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 793 HARLEM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PPE Testing, Mississippi Power Company 2023-01-01 2023-12-31 C001553 880 JACK MCDONOUGH, Generation, Attended 2023-01-01 2023-12-31 C001553 794 HARMONY BLUE GRANITE #1, Distribution, Unattended 2023-12-31 C001553 COBB PLACE, WOODSTOCK 230 KV LN, Steel Pole, 1351 ACSR 2023-01-01 2023-12-31 C001553 1168 MOUNT VERNON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1272 OLD ALABAMA ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1283 OLIVER ROAD, Distribution, Unattended 2023-12-31 C001553 1673 STANTON SPRINGS, Distribution, Unattended 2023-12-31 C001553 Grid Investment 2023-01-01 2023-12-31 C001553 1463 REYNOLDS, Distribution, Unattended 2023-12-31 C001553 1722 TALLULAH FALLS, Generation, Attended 2023-12-31 C001553 396 COOPER TIRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 106 BALDWIN, Distribution, Unattended 2023-12-31 C001553 1959 WHITEOAK, Transmission, Unattended 2023-01-01 2023-12-31 C001553 ferc:PropertyTaxMember 2023-12-31 C001553 1337 PERRY, Transmission, Unattended 2023-12-31 C001553 1375 PORTER PD, Distribution, Unattended 2023-12-31 C001553 GRP LLC, OS, 2023-01-01 2023-12-31 C001553 178 BOLIVAR, Distribution, Unattended 2023-12-31 C001553 963 LAKE LANIER, Distribution, Unattended 2023-12-31 C001553 1234 NORTH THOMASTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 841 HON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 868 INTERSTATE PAPER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 The Energy Authority, OS, 2023-01-01 2023-12-31 C001553 636 FOREST PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1128 MILLIKEN (Kingsley Mill) Thomson, Distribution, Unattended 2023-12-31 C001553 185 BONANZA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1521 SAINT MARYS ROAD, Distribution, Unattended 2023-12-31 C001553 Overstressed Or Obsolete Circuit Switcher Replacement ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 894 JAMESTOWN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1704 SUTTONS CROSSROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1139 MITCHELL 115, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1631 SOUTH RIVER WASTEWATER TREATMENT, Distribution, Unattended 2023-12-31 C001553 1393 PRAYON, Distribution, Unattended 2023-12-31 C001553 ferc:SchedulingSystemControlAndDispatchMember 2023-01-01 2023-12-31 C001553 1573 SHAW INDUSTRIES (Thomson), Distribution, Unattended 2023-12-31 C001553 Railcar Usage, Alabama Power Company 2023-01-01 2023-12-31 C001553 1790 TRENTON, Distribution, Unattended 2023-12-31 C001553 FSTOU-C Farm Service 2023-01-01 2023-12-31 C001553 32 ALEXANDER DRIVE, Distribution, Unattended 2023-12-31 C001553 663 FRANKLIN, Distribution, Unattended 2023-12-31 C001553 1416 PROPEX #7 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 633 FOLKSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1901 WALLACE DAM, Generation, Attended 2023-12-31 C001553 OL-Govt Outdoor Lighting - Governmental 2023-01-01 2023-12-31 C001553 849 HUNTER FIELD, Distribution, Unattended 2023-12-31 C001553 1898 WACO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 464 DEKALB COUNTY SEWAGE (Snapfinger Rd), Distribution, Unattended 2023-12-31 C001553 1373 POOLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 533 EAST DAWSON, Distribution, Unattended 2023-12-31 C001553 1014 LOOKOUT VALLEY, Transmission, Unattended 2023-12-31 C001553 309 CHEROKEE BRICK, Distribution, Unattended 2023-12-31 C001553 479 DEXTER, Distribution, Unattended 2023-12-31 C001553 SUTA, Payroll Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1706 SUWANEE, Transmission, Unattended 2023-12-31 C001553 1197 NEWTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 113 BARTLETTS FERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 South Mississippi Electric Power Association, OS, T4 2023-01-01 2023-12-31 C001553 1026 MABLETON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 806 HATCH, Generation, Attended 2023-12-31 C001553 1348 PILGRIMS PRIDE #1 (Athens), Distribution, Unattended 2023-12-31 C001553 571 ENCORE RECYCLING, Distribution, Unattended 2023-12-31 C001553 793 HARLEM, Distribution, Unattended 2023-12-31 C001553 Fiber Optics Spurs Construction ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Nuclear Decommissioning 2023-12-31 C001553 1788 TRENCH SHORING SERVICES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Utility Services Contracts (d) 2023-12-31 C001553 2015 YATES 6&7, Generation, Attended 2023-12-31 C001553 101 BAINBRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 541 EAST POINT, Distribution, Unattended 2023-12-31 C001553 967 LAKE SINCLAIR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1470 RINGGOLD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1829 U.S. POSTAL SERVICE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 OHARA, 230, 12.95, 702211 2023-01-01 2023-12-31 C001553 SUTA, Payroll Tax, Alabama, 2022-12-31 C001553 355 COCA COLA (Hapeville), Distribution, Unattended 2023-12-31 C001553 634 FOLKSTON, Distribution, Unattended 2023-12-31 C001553 1350 PILGRIMS PRIDE #3 (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1381 POTTERVILLE PM, Distribution, Unattended 2023-12-31 C001553 Coca Cola, LU, 2023-01-01 2023-12-31 C001553 202 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 859 INLAND ROME, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SOUTH ACWORTH 230 KV LN, 230, 6.71, 1280368 2023-01-01 2023-12-31 C001553 898 JEKYLL ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Distribution Projects Contribution In Aid Of Construction Offset ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ATLANTA WATER STORAGE (LOIS ST), NORTHWEST 115 KV, SSP, Overground 2023-01-01 2023-12-31 C001553 1930 WELCOME ALL ROAD, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, South Carolina, 2023-01-01 2023-12-31 C001553 714 GEORGIA TECH, Distribution, Unattended 2023-12-31 C001553 Office Building 2023-01-01 2023-12-31 C001553 932 KERRY #4 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 COVID-19 Costs 2023-01-01 2023-12-31 C001553 International Paper Port Wentworth, LU, 2023-01-01 2023-12-31 C001553 325 CHULA PD, Distribution, Unattended 2023-12-31 C001553 302 CHADBOURN GOTHAM, Distribution, Unattended 2023-12-31 C001553 1773 TIOGA, Transmission, Unattended 2023-12-31 C001553 1878 VOGTLE 230KV SWITCHING, Transmission, Unattended 2023-12-31 C001553 1307 PALMER CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 34 ALLATOONA HEIGHTS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:DirectPayrollDistributionMember 2023-01-01 2023-12-31 C001553 886 JACK MCDONOUGH CC #5, Generation, Attended 2023-12-31 C001553 1276 OLD MAUK ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 351 COBB MARIETTA WATER (Wyckoff), Distribution, Unattended 2023-12-31 C001553 257 BUTLER STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTDFPAC RTP Day Ahead - Fixed Pricing Alternative 2023-01-01 2023-12-31 C001553 59 ARAGON, Distribution, Unattended 2023-12-31 C001553 International Paper Qualified Facilities (QF), OS, 2023-01-01 2023-12-31 C001553 395 COOPER BRIDGE PM, Distribution, Unattended 2023-12-31 C001553 1071 MCDONOUGH CONSTRUCTION, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Steven R. Ewing 2023-01-01 2023-12-31 C001553 292 CEDAR SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 274 CARL FINDLEY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCINTOSH CT TIE 230KV, , , 0 2023-01-01 2023-12-31 C001553 760 GREENBRIAR, Distribution, Unattended 2023-12-31 C001553 276 CARMEUSE MINE #1 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 901 JESSIE PORCH ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1870 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 2008 WRIGHTSVILLE, Distribution, Unattended 2023-12-31 C001553 1339 PERRY, Transmission, Unattended 2023-12-31 C001553 976 LANZATECH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Conyers Renewable Power LLC, LU, 2023-01-01 2023-12-31 C001553 1849 VARNELL, Distribution, Unattended 2023-12-31 C001553 323 CHOKEE PLANTATION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1104 MELDRIM, Transmission, Unattended 2023-12-31 C001553 Monroe 1st Series 1995 - 2.25% 2023-12-31 C001553 1437 RAY MOUNTAIN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1800 TRONOX, Distribution, Unattended 2023-12-31 C001553 118 BASE MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1600 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1834 UNION POINT AREA #1 PM (RETIRED), Distribution, Unattended 2023-12-31 C001553 898 JEKYLL ISLAND, Distribution, Unattended 2023-12-31 C001553 520 DUNCAN BRIDGE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 268 CANDLER AREA PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1115 MIDVILLE, Distribution, Unattended 2023-12-31 C001553 784 HAHIRA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Post-Retirement Benefits and Pension-Associated Co 2023-01-01 2023-12-31 C001553 Bentina Terry 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 3 2023-12-31 C001553 1737 TEMPLE INDUSTRIES (Thomson), Distribution, Unattended 2023-12-31 C001553 1224 NORTH METTER, Distribution, Unattended 2023-12-31 C001553 828 HIGHWAY 16 PM (Eatonton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1974 WILMINGTON ISLAND, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1312 PARKDALE, Distribution, Unattended 2023-12-31 C001553 799 HARTSFIELD JACKSON, Distribution, Unattended 2023-12-31 C001553 1227 NORTH OCONEE WRF, Distribution, Unattended 2023-12-31 C001553 1512 ROTTENWOOD CREEK, Distribution, Unattended 2023-12-31 C001553 729 GOAT ROCK HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 1617 SOUTH GAINESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Lindsay Hill 2023-01-01 2023-12-31 C001553 779 GUTHRIE PM, Distribution, Unattended 2023-12-31 C001553 184 BONANZA, Distribution, Unattended 2023-12-31 C001553 1294 OXFORD ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 255 BUTLER, Distribution, Unattended 2023-12-31 C001553 562 ELLENWOOD, Distribution, Unattended 2023-12-31 C001553 FINANCING AUTHORITY APPLICATION - DOCKET NO. 44054 2023-01-01 2023-12-31 C001553 1202 NORMAN PARK ROAD PM, Distribution, Unattended 2023-12-31 C001553 161 BLAKELY PRIMARY, Transmission, Unattended 2023-12-31 C001553 R-M Residential: Multi-Unit 2023-01-01 2023-12-31 C001553 891 JACKSON COUNTY HEALTH CENTER PM, Distribution, Unattended 2023-12-31 C001553 1772 TIN BRIDGE PD, Distribution, Unattended 2023-12-31 C001553 1248 NORTHWEST 115, Distribution, Unattended 2023-12-31 C001553 429 CUMMING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1496 ROCHELLE, Distribution, Unattended 2023-12-31 C001553 431 CURRAHEE HEIGHTS, Distribution, Unattended 2023-12-31 C001553 482 DILLARD PRIMARY, Distribution, Unattended 2023-12-31 C001553 804 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 Ferc Relicensing Various Hydro Plants 2023-01-01 2023-12-31 C001553 40 AMERICAN GRANITE QUARRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1624 SOUTH MADISON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PLL-R Power & Light - Large 2023-01-01 2023-12-31 C001553 1985 WIND GAP FARMS, Distribution, Unattended 2023-12-31 C001553 291 CEDAR SPRINGS, Distribution, Unattended 2023-12-31 C001553 1097 MEADOWS LAKE #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 JACKSONVILLE ELECTRIC AUTHORITY JACKSONVILLE ELECTRIC AUTHORITY JEA LFP VOGTLE 103 2023-01-01 2023-12-31 C001553 1134 MILLIKEN (Pine Mountain), Distribution, Unattended 2023-12-31 C001553 SUTA, Payroll Tax, Alabama,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Floyd 1st Series 1996 - Variable 2023-01-01 2023-12-31 C001553 884 JACK MCDONOUGH CC #5, Generation, Attended 2023-12-31 C001553 947 KING STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 471 DELTA AIRLINES #2, Distribution, Unattended 2023-12-31 C001553 11 AIR PRODUCTS AND CHEMICALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1558 SCOTTDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1822 TYSON FOODS (Cumming), Distribution, Unattended 2023-01-01 2023-12-31 C001553 531 EAST BEACH, Distribution, Unattended 2023-12-31 C001553 1201 NORDIC COLD STORAGE (Hapeville), Distribution, Unattended 2023-12-31 C001553 1564 SEARS FASHION CENTER 25/4 KV, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SOUTH AUGUSTA 230 KV LN, 230, 14.83, 336767 2023-01-01 2023-12-31 C001553 Oil WILSON 2023-01-01 2023-12-31 C001553 298 CERTAINTEED (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1655 SOUTHWEST DUBLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1965 WIEUCA ROAD, Distribution, Unattended 2023-12-31 C001553 1187 NASHVILLE #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1837 UNITED PARCEL SERVICE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Disputed Payments 2023-01-01 2023-12-31 C001553 111 BARTLETTS FERRY, Transmission, Unattended 2023-12-31 C001553 727 GOAT ROCK #2, Distribution, Unattended 2023-12-31 C001553 RTDPLMI Real Time Pricing Day Ahead - Power & Light Medium 2023-01-01 2023-12-31 C001553 867 INTERSTATE PAPER, Distribution, Unattended 2023-12-31 C001553 1609 SOUTH AUGUSTA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1877 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 428 CUMBERLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 220 BROADWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1226 NORTH MONTICELLO, Transmission, Unattended 2023-12-31 C001553 781 GWINNETT COUNTY WFP (Shoal Creek), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Grid Modernization 2023-01-01 2023-12-31 C001553 1133 MILLIKEN (Pine Mountain), Distribution, Unattended 2023-01-01 2023-12-31 C001553 833 HINESVILLE PRIMARY, Transmission, Unattended 2023-12-31 C001553 1155 MORELAND WAY, Distribution, Unattended 2023-12-31 C001553 184 BONANZA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1742 TERRORA HYDRO, Generation, Attended 2023-12-31 C001553 Common Stock (all owned by Southern Company) 2022-01-01 2022-12-31 C001553 1455 REMLERS CORNER, Distribution, Unattended 2023-12-31 C001553 1538 SAVANNAH FOODS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1265 OCHLOCKNEE PRIMARY, Transmission, Unattended 2023-12-31 C001553 1528 SANDERSVILLE CLAY, Distribution, Unattended 2023-12-31 C001553 2336, LLOYD SHOALS 2023-12-31 C001553 287 CAVE SPRING #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Distribution New Business ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 998 LITHONIA, Distribution, Unattended 2023-12-31 C001553 308 CHEROKEE, Distribution, Unattended 2023-12-31 C001553 553 EATONTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 1553 SCHERER UNIT 3, Generation, Attended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Bethabara-E. Walton 230kv T/L Site 2023-01-01 2023-12-31 C001553 PowerSouth Electric Membership Co., OS, 2023-01-01 2023-12-31 C001553 TOUMBI Time of Use --Multiple business 2023-01-01 2023-12-31 C001553 850 HUNTSMAN PIGMENTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 849 HUNTER FIELD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1255 NUTRASWEET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 548 EASTANOLLEE, Distribution, Unattended 2023-12-31 C001553 1583 SINCLAIR DAM HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 1335 PENN CAMP ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 892 JACKSON COUNTY SENIOR CITIZENS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:RegulationAndFrequencyResponseMember 2023-01-01 2023-12-31 C001553 73 ASHFORD, Distribution, Unattended 2023-12-31 C001553 1178 MRS. SMITHS BAKERIES, Distribution, Unattended 2023-12-31 C001553 Ferc Relicensing Various Hydro Plants ferc:ElectricUtilityMember 2023-12-31 C001553 767 GREYSTONE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Additional Pension Deduction ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 117 BARTOW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 919 KAMIN (Wrens), Distribution, Unattended 2023-12-31 C001553 Stewart County ferc:LandAndRightsMember 2023-12-31 C001553 DOE Loan 2.178% - 2044 2023-12-31 C001553 1924 WAX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 System Flow Projects 2023-01-01 2023-12-31 C001553 3% 2023-01-01 2023-12-31 C001553 1193 NECO, Distribution, Unattended 2023-12-31 C001553 BOWEN 2023-12-31 C001553 1509 ROSSMAN PM, Distribution, Unattended 2023-12-31 C001553 1079 MCINTOSH CT, Generation, Attended 2023-01-01 2023-12-31 C001553 664 FRANKLIN, Distribution, Unattended 2023-12-31 C001553 555 EATONTON PUMPING PM, Distribution, Unattended 2023-12-31 C001553 Miscellaenous Transmission Line Replacements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 2354, MATHIS-TERRORA 2023-01-01 2023-12-31 C001553 28 ALAPAHA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Gas and Electric Hedges 2023-01-01 2023-12-31 C001553 354 2023-01-01 2023-12-31 C001553 Bartow 2nd Series 2009 2023-01-01 2023-12-31 C001553 1480 RIVERSTONE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 655 FORT MCPHERSON, Distribution, Unattended 2023-12-31 C001553 136 BELVEDERE, Distribution, Unattended 2023-12-31 C001553 Series 2021A - 3.25% 2023-01-01 2023-12-31 C001553 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock 2023-01-01 2023-12-31 C001553 Mark L. Burns 2023-01-01 2023-12-31 C001553 1942 WEST DICKEY PM, Distribution, Unattended 2023-12-31 C001553 Underground Addition & Improvements 2023-01-01 2023-12-31 C001553 515 DSM EVERGREEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 957 LAFARGE AGGREGATES #1 Douglasville, Distribution, Unattended 2023-12-31 C001553 1232 NORTH STATESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1328 PEACHTREE CORNERS, Distribution, Unattended 2023-12-31 C001553 1479 RIVERSIDE MILLS, Distribution, Unattended 2023-12-31 C001553 1482 RIVERWOOD #1 PM, Distribution, Unattended 2023-12-31 C001553 Burke 4th Series 1995 - 2.25% 2023-12-31 C001553 284 CASTLEBERRY ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 344 COBB COUNTY R. L. SUTTON WRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 770 GROVE POINT ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 839 HOLLY SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2019 YONAH, Generation, Attended 2023-01-01 2023-12-31 C001553 1675 STATENVILLE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 78 ATHENS PUMPING, Distribution, Unattended 2023-12-31 C001553 181 BOLTON, Distribution, Unattended 2023-12-31 C001553 1424 PYRAMAX CERAMICS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 126 BEASLEY TIMBER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Nuclear Fuel 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember Franchise Fees - 2023, Franchise Tax, Georgia, 2023-01-01 2023-12-31 C001553 1708 SWAINSBORO AREA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 511 DRURY PM, Distribution, Unattended 2023-12-31 C001553 1305 PALM STREET, Distribution, Unattended 2023-12-31 C001553 435 DAHLONEGA PRIMARY, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 27 ALADDIN MILLS (Forsyth), Distribution, Unattended 2023-12-31 C001553 SUTA, Payroll Tax, Georgia, 2023-01-01 2023-12-31 C001553 277 CARNESVILLE, Distribution, Unattended 2023-12-31 C001553 1743 TERRORA HYDRO, Generation, Attended 2023-12-31 C001553 1394 PREFERRED COMPOUNDING #1 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1975 WILMINGTON ISLAND, Transmission, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Georgia, 2023-01-01 2023-12-31 C001553 ferc:ElectricPollutionControlFacilitiesMember 2023-12-31 C001553 607 FIELDALE FARMS #2 (Murrayville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1946 WEST GRIFFIN, Distribution, Unattended 2023-12-31 C001553 1745 TEXTRON SPECIALITY PRODUCTS, Distribution, Unattended 2023-12-31 C001553 1098 MEADOWS SUBDIVISION PM, Distribution, Unattended 2023-12-31 C001553 74 ATHENA, Distribution, Unattended 2023-12-31 C001553 785 HAIRSTON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1874 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 Balancing Operating Reserve 2023-01-01 2023-06-30 C001553 Riverview - Retired (E) 2023-01-01 2023-12-31 C001553 1131 MILLIKEN (New Holland) Gainesville, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SAVANNAH 230 KV LN, 230, 16.06, 338213 2023-01-01 2023-12-31 C001553 NTE Carolinas, SF, 2023-01-01 2023-12-31 C001553 GPC Vogtle 3&4 Construction Payments 2023-01-01 2023-12-31 C001553 148 BICKERSTAFF CLAY PRODUCTS, Distribution, Unattended 2023-12-31 C001553 South Augusta, 230, 4.02, 12051 2023-01-01 2023-12-31 C001553 Series 2009A - 5.95% 2023-12-31 C001553 Georgia Power Company Rate Schedule No. 837 , ER24-457-000 2023-01-01 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 FLORIDA POWER & LIGHT COMPANY EXELON GENERATION COMPANY, LLC GTC LFP SOCOGEN 124 2023-01-01 2023-12-31 C001553 1631 SOUTH RIVER WASTEWATER TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1417 PROPEX #7 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1044 MANN ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:CaptialStockMember 2023-12-31 C001553 444 DAVIE SLICE PM, Distribution, Unattended 2023-12-31 C001553 Star Thread - Barnett Shoals Inc, LU, 2023-01-01 2023-12-31 C001553 Series 2013A - 4.3% 2023-12-31 C001553 1663 SPIRIT CREEK, Distribution, Unattended 2023-12-31 C001553 554 EATONTON PUMPING PM, Distribution, Unattended 2023-12-31 C001553 Transmission 2023-01-01 2023-12-31 C001553 1924 WAX, Distribution, Unattended 2023-12-31 C001553 WARNER ROBINS Oil 2023-01-01 2023-12-31 C001553 1163 MOSSY BRANCH BATTERY STORAGE, Generation, Attended 2023-01-01 2023-12-31 C001553 SCOTTDALE-BLVD 230 KV LN, 230, 23.69, 648919 2023-01-01 2023-12-31 C001553 RTPHGC RTP Hour Ahead/G-COM 2023-01-01 2023-12-31 C001553 334 CLAYTON MARCUS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1647 SOUTHERN NATURAL GAS (Ellerslie), Distribution, Unattended 2023-12-31 C001553 241 BUFORD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1207 NORTH CONYERS, Distribution, Unattended 2023-12-31 C001553 1638 SOUTHEASTERN ASSEMBLY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 306 CHATTAHOOCHEE, Distribution, Unattended 2023-12-31 C001553 769 GRIFFIN ROAD, Distribution, Unattended 2023-12-31 C001553 Piedmont Forrest Corporation ferc:EquityContributionMember 2023-01-01 2023-12-31 C001553 173 BOBBY JONES, Distribution, Unattended 2023-12-31 C001553 Solar Self Build Projects ferc:ElectricUtilityMember 2023-12-31 C001553 ferc:FranchiseTaxMember 2022-12-31 C001553 50 ANTHONY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 455 DEAL BRANCH, Transmission, Unattended 2023-01-01 2023-12-31 C001553 12 AIRGAS (Pendergrass), Distribution, Unattended 2023-12-31 C001553 ferc:OtherAncillaryServicesMember 2023-01-01 2023-12-31 C001553 1260 OAK STREET, Distribution, Unattended 2023-12-31 C001553 1771 TIMBERMEN (Camak), Distribution, Unattended 2023-01-01 2023-12-31 C001553 48 ANGLO AMERICAN CLAY TEMPORARY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1825 U.S. MARINE CORPS (MOCK ROAD), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1240 NORTH VALDOSTA, Distribution, Unattended 2023-12-31 C001553 1107 MENLO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1468 RIDGEWAY CHURCH ROAD, Distribution, Unattended 2023-12-31 C001553 Fixed Assets 2023-01-01 2023-12-31 C001553 1767 THREE RIVERS PM, Distribution, Unattended 2023-12-31 C001553 NORTH CAROLINA ELECTRIC MEMBERSHIP CORPORATION North Carolina Electric Membership Corporation DUK LFP DAHLBERG 44 2023-01-01 2023-12-31 C001553 1585 SIX MILE, Distribution, Unattended 2023-12-31 C001553 DOE Loan 3.002% - 2044 2023-12-31 C001553 1970 WILLINGHAM DRIVE, Distribution, Unattended 2023-12-31 C001553 1911 WARM SPRINGS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1429 QUINTON DILLINGHAM PM, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Georgia, 2023-12-31 C001553 404 CORNELIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 316 CHICOPEE WOODS PM, Distribution, Unattended 2023-12-31 C001553 Burke 1st Series 2009 - Variable 2023-12-31 C001553 704 GEORGIA PACIFIC (Sterling), Distribution, Unattended 2023-01-01 2023-12-31 C001553 SLM School Load Management 2023-01-01 2023-12-31 C001553 187 BORAL BRICK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1222 NORTH MARTIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 310 CHEROKEE ROAD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1410 PROPEX #4 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1643 SOUTHERN LNG, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Federal Income Taxes 2022 & Prior, Income Tax, , 2023-01-01 2023-12-31 C001553 946 KING STREET, Distribution, Unattended 2023-12-31 C001553 1430 R. M. MOORE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1974 WILMINGTON ISLAND, Transmission, Unattended 2023-12-31 C001553 Burke 1st Series 2009 - Variable 2023-01-01 2023-12-31 C001553 CENTER 230 KV LN, 230, 9.46, 222516 2023-01-01 2023-12-31 C001553 ScheduleRegionalTransmissionServiceRevenuesAbstract 2023-01-01 2023-12-31 C001553 1516 ROYSTON MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2020A - 2.10% 2023-01-01 2023-12-31 C001553 294 CEDARTOWN, Transmission, Unattended 2023-12-31 C001553 82 ATLANTA WATER TREATMENT (Bolton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1632 SOUTH TIFTON, Distribution, Unattended 2023-12-31 C001553 981 LEESBURG, Distribution, Unattended 2023-12-31 C001553 1345 PHARMATECH, Distribution, Unattended 2023-12-31 C001553 1321 PCS NITROGEN, Distribution, Unattended 2023-12-31 C001553 MORGANVILLE, TVA 230KV LN, Wood H-Frame, 477 ACSR 2023-01-01 2023-12-31 C001553 DOE Loan 3.142% - 2044 2023-12-31 C001553 1119 MILLEDGEVILLE, Distribution, Unattended 2023-12-31 C001553 1754 THIELE KAOLIN (Sandersville), Distribution, Unattended 2023-12-31 C001553 Customer Service System (CSS) Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 63 ARGOS (Atlanta), Distribution, Unattended 2023-12-31 C001553 787 HAMILTON CROSSING ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1042 MALL OF GEORGIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 589 EVANS PRIMARY, Transmission, Unattended 2023-12-31 C001553 968 LAKE SUSIE PM, Distribution, Unattended 2023-12-31 C001553 Distribution New Business 2023-01-01 2023-12-31 C001553 62 ARCHER DANIELS MIDLAND (Valdosta), Distribution, Unattended 2023-01-01 2023-12-31 C001553 85 ATLANTIC DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 14 AIRLINE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 325 CHULA PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1576 SHILOH, Distribution, Unattended 2023-12-31 C001553 Southern Electric Generating Co. (4th Issuance)ferc:CaptialStockMember 2022-12-31 C001553 1241 NORTHCREST, Distribution, Unattended 2023-12-31 C001553 256 BUTLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1937 WEST AUGUSTA, Distribution, Unattended 2023-12-31 C001553 20221103-5192, 44868, ER10-171-000 2023-01-01 2023-12-31 C001553 1522 SAINT MARYS ROAD, Distribution, Unattended 2023-12-31 C001553 1949 WEST POINT FOUNDRY & MACHINE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DEAN FOREST 230KV , 230, 5.5, 3043377 2023-01-01 2023-12-31 C001553 1636 SOUTHEAST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FPA- COM Fixed Pricing Alternative 2023-01-01 2023-12-31 C001553 351 COBB MARIETTA WATER (Wyckoff), Distribution, Unattended 2023-01-01 2023-12-31 C001553 KGen Sandersville LLC, OS, T5 2023-01-01 2023-12-31 C001553 563 ELLERSLIE, Distribution, Unattended 2023-12-31 C001553 628 FLIPPEN, Distribution, Unattended 2023-12-31 C001553 1944 WEST DUBLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Transmission Solar Interconnection (c) 2023-01-01 2023-12-31 C001553 251 BURTON, Distribution, Unattended 2023-12-31 C001553 McGrau Ford BESS Site ferc:LandAndRightsMember 2023-01-01 2023-12-31 C001553 993 LINWOOD WRF, Distribution, Unattended 2023-12-31 C001553 1110 METAL PRODUCTS #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 686 GEO SPECIALTY CHEMICAL (HENKEL), Distribution, Unattended 2023-01-01 2023-12-31 C001553 53 ANTIOCH ROAD, Distribution, Unattended 2023-12-31 C001553 1174 MOUNTAIN SPRINGS #1 PM, Distribution, Unattended 2023-12-31 C001553 Savannah Portside International- Old River Road Substation Site ferc:LandAndRightsMember 2023-12-31 C001553 646 FORT BENNING #2, Transmission, Unattended 2023-01-01 2023-12-31 C001553 201 BOWEN, Generation, Attended 2023-12-31 C001553 155 BILL FRANKS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 204 BOWEN, Generation, Attended 2023-12-31 C001553 EAST POINT 230 KV LN, 230, 30.56, 88651 2023-01-01 2023-12-31 C001553 811 HATCH, Generation, Attended 2023-12-31 C001553 322 CHOKEE PLANTATION PM, Distribution, Unattended 2023-12-31 C001553 1727 TALONA PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Substance Abuse Testing 2023-01-01 2023-12-31 C001553 1967 WILLACOOCHEE CITY, Distribution, Unattended 2023-12-31 C001553 1750 THE ROCK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 486 DIXIE PECAN PM, Distribution, Unattended 2023-12-31 C001553 1888 VULCAN MATERIALS (Madras), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1988 WINDWARD, Distribution, Unattended 2023-12-31 C001553 949 KINGSLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1136 MILLIRONS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 3.488% - 2044 2023-01-01 2023-12-31 C001553 860 INLAND ROME, Distribution, Unattended 2023-12-31 C001553 20221101-5088, 44866, ER10-171-000 2023-01-01 2023-12-31 C001553 1494 ROBINS CT, Generation, Attended 2023-01-01 2023-12-31 C001553 Vacation Pay Accrued 2022-12-31 C001553 600 FAYETTEVILLE ROAD, Distribution, Unattended 2023-12-31 C001553 Administrative & Other Related Services, Southern Company Services 2023-01-01 2023-12-31 C001553 1364 PLANTATION PIPELINE (Lafayette), Distribution, Unattended 2023-01-01 2023-12-31 C001553 132 BEKAERT STEEL WIRE, Distribution, Unattended 2023-12-31 C001553 1203 NORTH ATHENS, Distribution, Unattended 2023-12-31 C001553 1003 LITTLE RIVER, Distribution, Unattended 2023-12-31 C001553 Monroe 1st Series 1995 - 2.25% 2023-01-01 2023-12-31 C001553 1854 VIDALIA, Distribution, Unattended 2023-12-31 C001553 1072 MCGRAU FORD, Transmission, Unattended 2023-12-31 C001553 1904 WALTHOURVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Federal Income Taxes 2022 & Prior, Income Tax, , 2023-12-31 C001553 925 KEDRON, Distribution, Unattended 2023-12-31 C001553 254 BUTLER, Distribution, Unattended 2023-12-31 C001553 VOGTLE, WADLEY 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 547 EASTANOLLEE, Distribution, Unattended 2023-12-31 C001553 195 BOWEN, Generation, Attended 2023-12-31 C001553 742 GOSHEN (Savannah), Distribution, Unattended 2023-12-31 C001553 235 BUCKHEAD PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 661 FOWLER STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1660 SPALDING DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1239 NORTH VALDOSTA, Distribution, Unattended 2023-12-31 C001553 22 ALADDIN MILLS, Distribution, Unattended 2023-12-31 C001553 Associated Sales – Mississippi Power Company ferc:NitrogenOxideMember 2023-01-01 2023-12-31 C001553 Bartow 1st Series 2013 - 2.88% 2023-01-01 2023-12-31 C001553 1337 PERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1501 ROME, Distribution, Unattended 2023-12-31 C001553 59 ARAGON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Administrative Fees 2023-01-01 2023-03-31 C001553 201 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1986 WINDER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Calpine Energy Services, OS, 2023-01-01 2023-12-31 C001553 604 FERGUSON AVENUE, Transmission, Unattended 2023-12-31 C001553 705 GEORGIA PACIFIC (Vienna), Distribution, Unattended 2023-01-01 2023-12-31 C001553 GS-C General Service 2023-01-01 2023-12-31 C001553 1005 LLOYD SHOALS, Transmission, Attended 2023-12-31 C001553 1232 NORTH STATESBORO, Distribution, Unattended 2023-12-31 C001553 1555 SCHERER UNIT 4, Generation, Attended 2023-01-01 2023-12-31 C001553 162 BLANCHARD INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1733 TAYLORSVILLE, Distribution, Unattended 2023-12-31 C001553 579 ERCO WORLDWIDE, Distribution, Unattended 2023-12-31 C001553 71 ASHBURN PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 428 CUMBERLAND, Distribution, Unattended 2023-12-31 C001553 LITTLE OGEECHEE (BLACK) 230, 230, 24.33, 0 2023-01-01 2023-12-31 C001553 1298 PACKAGING CORPORATION (Macon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 535 EAST EVANS, Distribution, Unattended 2023-12-31 C001553 665 FRANKLIN ALUMINUM, Distribution, Unattended 2023-12-31 C001553 573 ENGELHARD (McIntyre), Distribution, Unattended 2023-12-31 C001553 1109 MERIWETHER ROAD, Distribution, Unattended 2023-12-31 C001553 851 HUSQVARNA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1217 NORTH JEFFERSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1866 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 105 BALDWIN, Distribution, Unattended 2023-12-31 C001553 KINGS BAY #2 230 KV LN, 230, 7.87, 13429 2023-01-01 2023-12-31 C001553 Other Clearing Accounts 2023-01-01 2023-12-31 C001553 Steam 2023-01-01 2023-12-31 C001553 1327 PEACHTREE CITY #2, Distribution, Unattended 2023-12-31 C001553 358 CODY ROAD, Distribution, Unattended 2023-12-31 C001553 1782 TOTO, Distribution, Unattended 2023-12-31 C001553 Series 2019B - 2.65% 2023-01-01 2023-12-31 C001553 630 FLOWERY BRANCH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 100 BAINBRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 857 INDUSTRIAL BOULEVARD, Distribution, Unattended 2023-12-31 C001553 138 BELVEDERE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 631 FLOWERY BRANCH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1692 STONEY BROOK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1121 MILLEN AREA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTHRN-C RTP Hour Ahead - Revenue Neutral 2023-01-01 2023-12-31 C001553 RENEWABLES AND GREEN ENERGY - DOCKET NO. 43107,43085, 43814, and 43985 2023-12-31 C001553 645 FORT BENNING, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1598 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1935 WEST 11TH STREET, Distribution, Unattended 2023-12-31 C001553 1308 PALMYRA, Distribution, Unattended 2023-12-31 C001553 456 DEAN FOREST, Transmission, Unattended 2023-12-31 C001553 1124 MILLHAVEN ANNEX, Transmission, Unattended 2023-12-31 C001553 1310 PARK, Distribution, Unattended 2023-12-31 C001553 Christopher C. Womack 2023-01-01 2023-12-31 C001553 ferc:JanuaryMember Georgia Power Company 2023-01-01 2023-12-31 C001553 832 HINESVILLE PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 933 KETTLE CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 748 GRADY, Distribution, Unattended 2023-12-31 C001553 Rainbow Energy Marketing Corporation, OS, 2023-01-01 2023-12-31 C001553 South Carolina Public Service Authority, OS, T4 2023-01-01 2023-12-31 C001553 (6) OTHER, Research Administration 930.2 2023-01-01 2023-12-31 C001553 Walton Electric Membership Corporation, OS, T4 2023-01-01 2023-12-31 C001553 1589 SMITHVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1530 SANDY SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1855 VIDALIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2021-12-31 C001553 615 FIRST UNITED ETHANOL, Distribution, Unattended 2023-12-31 C001553 South Carolina Electric & Gas Company, OS, T4 2023-01-01 2023-12-31 C001553 1752 THIELE KAOLIN (Mine), Distribution, Unattended 2023-12-31 C001553 557 ECHECONNEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1164 MOULTRIE, Distribution, Unattended 2023-12-31 C001553 1765 THOMSON PRIMARY, Transmission, Unattended 2023-12-31 C001553 Meredith M. Lackey 2023-01-01 2023-12-31 C001553 SOUTH HALL 230 KV LN, , , 0 2023-01-01 2023-12-31 C001553 Premium on Reacquired Debt 2023-01-01 2023-12-31 C001553 Doraville Balance of Substation Upgrades 2023-01-01 2023-12-31 C001553 City of Hartford City of Hartford City of Hartford FNO N/A 3 2023-01-01 2023-12-31 C001553 1282 OLIVER DAM HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 1697 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1022 LUMBER CITY, Distribution, Unattended 2023-12-31 C001553 Nuclear Decommissioning 2023-01-01 2023-12-31 C001553 1670 STANDRIDGE COLOR #1, Distribution, Unattended 2023-12-31 C001553 ferc:HydraulicProductionPlantPumpedStorageMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Mississippi, 2023-12-31 C001553 273 CANYON ROAD, Distribution, Unattended 2023-12-31 C001553 Plant McDonough - Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 1235 NORTH THOMSON, Distribution, Unattended 2023-12-31 C001553 Bartow 2nd Series 2009 2023-01-01 2023-12-31 C001553 1103 MEIGS, Distribution, Unattended 2023-12-31 C001553 1535 SASSER, Distribution, Unattended 2023-12-31 C001553 1274 OLD DALTON ROAD, Distribution, Unattended 2023-12-31 C001553 1294 OXFORD ROAD, Distribution, Unattended 2023-12-31 C001553 1434 RAINBOW DRIVE, Distribution, Unattended 2023-12-31 C001553 1702 SUNSHINE BISCUIT (Columbus), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1370 POMONA, Distribution, Unattended 2023-12-31 C001553 Renewable Generation Collateral 2022-12-31 C001553 Plant Scherer - Water 2023-01-01 2023-12-31 C001553 616 FISHING CREEK, Distribution, Unattended 2023-12-31 C001553 1462 RETTCO STEEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 593 FACTORY SHOALS ROAD, Distribution, Unattended 2023-12-31 C001553 1712 SWEET CITY PD, Distribution, Unattended 2023-12-31 C001553 Plant Wilson CT - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 214 BRENTWOOD, Distribution, Unattended 2023-12-31 C001553 236 BUDWEISER PM, Distribution, Unattended 2023-12-31 C001553 32 ALEXANDER DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 New Business ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1008 LOCH LAUREL, Distribution, Unattended 2023-12-31 C001553 1955 WHITE BLUFF, Transmission, Unattended 2023-01-01 2023-12-31 C001553 560 ELBERTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1029 MACON COUNTY PRISON #1 PD (South), Distribution, Unattended 2023-12-31 C001553 Estatoah - Retired (C) 2023-01-01 2023-12-31 C001553 City of Troy, Alabama, OS, T5 2023-01-01 2023-12-31 C001553 617 FITZGERALD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 505 DORSEY TRAILERS #2 PM, Distribution, Unattended 2023-12-31 C001553 156 BLACK BEAR PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 753 GRAPHIC PACKAGING (Augusta), Distribution, Unattended 2023-12-31 C001553 1580 SILK HOPE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1575 SHENANDOAH SEWAGE PM, Distribution, Unattended 2023-12-31 C001553 1214 NORTH HIGHLANDS, Generation, Attended 2023-01-01 2023-12-31 C001553 38 ALTO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1192 NECO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Georgia, 2022-12-31 C001553 Customer Data Usage 2023-01-01 2023-12-31 C001553 WINDER 230 KV LN, 230, 38.62, 146497 2023-01-01 2023-12-31 C001553 492 DIXIE PIPELINE (Norwood), Distribution, Unattended 2023-12-31 C001553 WM Renewable Energy, LLC, OS, 2023-01-01 2023-12-31 C001553 65 ARMSTRONG GLASS (Jasper), Distribution, Unattended 2023-01-01 2023-12-31 C001553 370 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Lewiston Road Substation Site 2023-12-31 C001553 315 CHICOPEE MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 903 JEWELL, Distribution, Unattended 2023-12-31 C001553 2010 WYNNTON, Distribution, Unattended 2023-12-31 C001553 1653 SOUTHERN WOOD SUPPLIES, Distribution, Unattended 2023-12-31 C001553 1645 SOUTHERN MILLS #2 (Senoia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1668 SPRINGFIELD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1006 LLOYD SHOALS HYDRO, Generation, Attended 2023-12-31 C001553 Chatsworth Water Works, LU, 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Boyd Ave Substation Site 2023-12-31 C001553 421 CRYSTAL BLUE GRANITE PM, Distribution, Unattended 2023-12-31 C001553 507 DOSTER ROAD #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1707 SWAINSBORO AREA #1 PM, Distribution, Unattended 2023-12-31 C001553 1941 WEST DALLAS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1986 WINDER PRIMARY, Distribution, Unattended 2023-12-31 C001553 ScheduleCommonUtilityPlantAndExpensesAbstract 2023-01-01 2023-12-31 C001553 Net Worth, Other License And Fees Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 DOE Loan 3.072% - 2044 2023-12-31 C001553 719 GERDAU, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1879 VOGTLE 3&4 500KV, Generation, Attended 2023-12-31 C001553 76 ATHENS OPERATING PM, Distribution, Unattended 2023-12-31 C001553 702 GEORGIA PACIFIC (Ellabell), Distribution, Unattended 2023-12-31 C001553 Amortization of 2023-01-01 2023-12-31 C001553 699 GEORGIA MARBLE (Tate), Distribution, Unattended 2023-01-01 2023-12-31 C001553 666 FREDERICA, Distribution, Unattended 2023-12-31 C001553 1117 MILL CITY SEWAGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1971 WILLINGHAM DRIVE, Distribution, Unattended 2023-12-31 C001553 North Carolina Municipal Power Agency #1, OS, 2023-01-01 2023-12-31 C001553 2016 YATES 6&7, Generation, Attended 2023-12-31 C001553 359 COLEMAN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 683 GARDEN CITY, Distribution, Unattended 2023-12-31 C001553 1242 NORTHEAST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 1846 VALDOSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Asset Retirement Obligations 2023-01-01 2023-12-31 C001553 Medical Arts Substation Site 2023-01-01 2023-12-31 C001553 1758 THOMASTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1869 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 MORROW 230 KV LN, 230, 23.39, 375087 2023-01-01 2023-12-31 C001553 Thomas M. Holder 2023-01-01 2023-12-31 C001553 777 GULFSTREAM HANGAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 174 BOBBY JONES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 583 EUCHEE CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1184 MYSTERY VALLEY, Distribution, Unattended 2023-12-31 C001553 Miscellaneous Distribution Substation Additions & Improvements 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Substation Additions & Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 349 COBB MARIETTA WATER (Lower Roswell), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1796 TRIBUTARY, Transmission, Unattended 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (1st Issuance) 2023-12-31 C001553 673 GA ARMY NATIONAL GUARD, Distribution, Unattended 2023-12-31 C001553 282 CASCADE HEIGHTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 13 AIRGAS (Pendergrass), Distribution, Unattended 2023-12-31 C001553 1106 MELDRIM, Transmission, Unattended 2023-01-01 2023-12-31 C001553 459 DECATUR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE 3 2023-01-01 2023-12-31 C001553 1120 MILLEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 60 ARAGON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1711 SWAINSBORO PRIMARY, Distribution, Unattended 2023-12-31 C001553 ferc:OtherUtilityMember 2023-12-31 C001553 143 BERKELEY LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 EVANS 230 KV LN, 230, 72.93, 240420 2023-01-01 2023-12-31 C001553 SASND-I Seasonal Agricultural Service - Non-Demand 2023-01-01 2023-12-31 C001553 527 EAST ATHENS, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Mississippi, 2022-12-31 C001553 447 DAVIS STREET, Transmission, Unattended 2023-12-31 C001553 PERIMETER CENTER 230 KV LN, 230, 6.08, 271276 2023-01-01 2023-12-31 C001553 1491 ROBINS AFB #4 - W.D. Fowler, Distribution, Unattended 2023-12-31 C001553 1834 UNION POINT AREA #1 PM (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 855 IDLEWOOD, Distribution, Unattended 2023-12-31 C001553 1086 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 826 HIGHTOWER ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1685 STILESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2023, Property Tax, Georgia, 2023-12-31 C001553 City of Tallahassee, Florida, OS, T4 2023-01-01 2023-12-31 C001553 259 CADWELL PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1378 PORTERDALE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 2nd Series 2008 - 2.93% 2023-01-01 2023-12-31 C001553 MCDONOUGH CC #6 230 KV TIE LINE, 230, 0.34, 0 2023-01-01 2023-12-31 C001553 ferc:CurrentYearMember ferc:NitrogenOxideMember 2023-12-31 C001553 1130 MILLIKEN (Lagrange), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1456 REMLERS CORNER, Distribution, Unattended 2023-12-31 C001553 1077 MCINTOSH CC, Generation, Attended 2023-12-31 C001553 1444 RED DOG FARM ROAD PM, Distribution, Unattended 2023-12-31 C001553 691 GEORGIA BIOMASS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 JOHNSON FY-DERING CIR, 230, 0.2, 15198 2023-01-01 2023-12-31 C001553 1677 STATESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Energy Efficiency Improvements 2023-01-01 2023-12-31 C001553 1176 MOUNTAIN VIEW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1399 PRESTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1429 QUINTON DILLINGHAM PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1768 TIFTON PRIMARY, Distribution, Unattended 2023-12-31 C001553 1578 SHURLING DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 177 BOJO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1748 THE BRIDGE CHURCH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 566 ELLIJAY PRIMARY, Transmission, Unattended 2023-12-31 C001553 230 BROWN FARM ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 331 CLARKSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1666 SPRING STREET, Distribution, Unattended 2023-12-31 C001553 1876 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 565 ELLIJAY LUMBER, Distribution, Unattended 2023-12-31 C001553 1593 SMYRNA, Distribution, Unattended 2023-12-31 C001553 242 BUFORD, Distribution, Unattended 2023-12-31 C001553 1914 WARRENTON AREA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 798 HARTSFIELD JACKSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 419 CROSSGATE, Transmission, Unattended 2023-12-31 C001553 804 HATCH, Generation, Attended 2023-12-31 C001553 1601 SOLO CUP #1, Distribution, Unattended 2023-12-31 C001553 1615 SOUTH DAHLONEGA, Distribution, Unattended 2023-12-31 C001553 Series 2017B - 3.25% 2023-12-31 C001553 1565 SEVENTH AVENUE, Distribution, Unattended 2023-12-31 C001553 Deferred Plant Depreciation 2023-12-31 C001553 885 JACK MCDONOUGH CC #5, Generation, Attended 2023-12-31 C001553 Series 2016A - 3.25% 2023-01-01 2023-12-31 C001553 539 EAST MAYSVILLE, Distribution, Unattended 2023-12-31 C001553 IKEA Savannah, LU, 2023-01-01 2023-12-31 C001553 551 EATONTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1402 PROCTER & GAMBLE (Albany), Distribution, Unattended 2023-01-01 2023-12-31 C001553 421 CRYSTAL BLUE GRANITE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 178 BOLIVAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 YATES 2023-12-31 C001553 126 BEASLEY TIMBER, Distribution, Unattended 2023-12-31 C001553 842 HONDA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 17 ALADDIN FIBER ONE #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:SulfurDioxideMember ferc:CurrentYearMember 2023-12-31 C001553 1221 NORTH MACON, Distribution, Unattended 2023-12-31 C001553 1379 PORTERDALE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1083 MCINTOSH TRAIL, Distribution, Unattended 2023-12-31 C001553 1219 NORTH KEITHSBURG, Distribution, Unattended 2023-12-31 C001553 133 BELAIR, Distribution, Unattended 2023-12-31 C001553 321 CHLORIDE, Distribution, Unattended 2023-12-31 C001553 1ST AVE COLUMBUS #2 230 KV , 230, , 0 2023-01-01 2023-12-31 C001553 Utoy Springs Substation Site ferc:LandAndRightsMember 2023-12-31 C001553 1296 PACKAGING CORPORATION (Clyattville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 691 GEORGIA BIOMASS, Distribution, Unattended 2023-12-31 C001553 183 BOLTON STREET, Distribution, Unattended 2023-12-31 C001553 362 COLONELS ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 1st Series 2012 - 2.88% 2023-12-31 C001553 208 BOWEN PUMPING, Distribution, Attended 2023-01-01 2023-12-31 C001553 730 GOAT ROCK HYDRO, Generation, Attended 2023-12-31 C001553 402 CORINTH ROAD, Distribution, Unattended 2023-12-31 C001553 1467 RICHMOND HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Hickory Park Solar LLC, LU, 2023-01-01 2023-12-31 C001553 1806 TUCKER, Distribution, Unattended 2023-12-31 C001553 1286 ORANGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1727 TALONA PM, Distribution, Unattended 2023-12-31 C001553 1780 TOMMY FIELDS PM, Distribution, Unattended 2023-12-31 C001553 1933 WESLEYAN DRIVE, Distribution, Unattended 2023-12-31 C001553 1629 SOUTH OGLETHORPE, Distribution, Unattended 2023-12-31 C001553 1900 WALLACE DAM, Generation, Attended 2023-12-31 C001553 1474 RIVER ROAD, Distribution, Unattended 2023-12-31 C001553 207 BOWEN NPDES, Distribution, Attended 2023-01-01 2023-12-31 C001553 CENTER 230 KV LN, 230, 22.91, 538883 2023-01-01 2023-12-31 C001553 1046 MAR-JAC POULTRY #1, Distribution, Unattended 2023-12-31 C001553 COOSAWATTEE 230 KV LN, 230, 0.46, 0 2023-01-01 2023-12-31 C001553 973 LAKEWOOD, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Alabama,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 899 JENNINGS PM, Distribution, Unattended 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (2nd Issuance) 2023-12-31 C001553 582 ETON, Distribution, Unattended 2023-12-31 C001553 Deferred Plant Retirement Costs 2023-01-01 2023-12-31 C001553 690 GEORGIA BAPTIST VILLAGE, Distribution, Unattended 2023-12-31 C001553 1344 PHARMATECH, Distribution, Unattended 2023-12-31 C001553 385 CONCORD GROVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1684 STEVENS CREEK, Transmission, Unattended 2023-01-01 2023-12-31 C001553 ferc:OtherUtilityMember Other (Specify) 2022-12-31 C001553 441 DANIMER, Distribution, Unattended 2023-12-31 C001553 1787 TRANSCO, Distribution, Unattended 2023-12-31 C001553 LITTLE OGEECHEE 230 KV LN, 230, 21.9, 2410129 2023-01-01 2023-12-31 C001553 1586 SKIDAWAY ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 717 GERDAU, Distribution, Unattended 2023-12-31 C001553 Tennessee Valley Authority, OS, 2023-01-01 2023-12-31 C001553 1909 WANSLEY PUMPING, Distribution, Unattended 2023-12-31 C001553 FORT GORDON 2023-12-31 C001553 8 ADDLESTONE, Distribution, Unattended 2023-12-31 C001553 299 CERTAINTEED (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 529 EAST BAINBRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1299 PACTIV #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1663 SPIRIT CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1226 NORTH MONTICELLO, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Plant Vogtle 1&2 - Controls ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 b. Fossil-fuel steam, Advanced Power Plant 506 2023-01-01 2023-12-31 C001553 1816 TYBEE ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Florida Power & Light Company, OS, T4 2023-01-01 2023-12-31 C001553 1040 MAIN STREET PD (RETIRED), Distribution, Unattended 2023-12-31 C001553 Heard 1st Series 1997 - Variable 2023-01-01 2023-12-31 C001553 OCEE, 230, 10.86, 208073 2023-01-01 2023-12-31 C001553 1816 TYBEE ISLAND, Distribution, Unattended 2023-12-31 C001553 1136 MILLIRONS ROAD, Distribution, Unattended 2023-12-31 C001553 Plant Hatch - Controls ferc:ElectricUtilityMember 2023-12-31 C001553 1703 SUPER SOD FARM PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 636 FOREST PARK, Distribution, Unattended 2023-12-31 C001553 2177, NORTH HIGHLANDS 2023-01-01 2023-12-31 C001553 172 BOAT ROCK ROAD, Distribution, Unattended 2023-12-31 C001553 390 2023-01-01 2023-12-31 C001553 Grid Modernization ferc:ElectricUtilityMember 2023-12-31 C001553 619 FLAT CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1101 MEDUSA PORTLAND CEMENT #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 332 CLAXTON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 DOCKET ITEMS UNDER $25,000 (7 2023-12-31 C001553 1549 SCHERER UNIT 2, Generation, Attended 2023-01-01 2023-12-31 C001553 1258 OAK GROVE, Distribution, Unattended 2023-12-31 C001553 290 CEDAR HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 383 COMOLLI GRANITE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1220 NORTH KITE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 966 LAKE RIDGE PARKWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Vogtle Units 3&4 Construction ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 578 ERCO WORLDWIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1160 MORGANVILLE, Distribution, Unattended 2023-12-31 C001553 Environmental Remediation 2023-12-31 C001553 MCINTOSH (WHITE) 230 KV (SA, 230, 8.23, 0 2023-01-01 2023-12-31 C001553 1534 SARGENT, Distribution, Unattended 2023-12-31 C001553 418 CROOKED RIVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1231 NORTH SPRINGS, Distribution, Unattended 2023-12-31 C001553 SCHERER, WALLACE DAM 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 1439 RAYONIER (Eatonton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1614 SOUTH COLUMBUS, Distribution, Unattended 2023-12-31 C001553 1775 TOCCOA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1403 PROFILE EXTRUSIONS PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1618 SOUTH GAINESVILLE, Distribution, Unattended 2023-12-31 C001553 FLAR-R Flat Bill - Residential 2023-01-01 2023-12-31 C001553 TOURN-C Time of Use Revenue Neutral 2023-01-01 2023-12-31 C001553 1504 ROPER INDUSTRIES #2 (RETIRED), Distribution, Unattended 2023-12-31 C001553 453 DAWSON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1338 PERRY, Transmission, Unattended 2023-12-31 C001553 1824 U.S. CAN (Tallapoosa), Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Tennessee, 2023-01-01 2023-12-31 C001553 1915 WARRENTON AREA #3 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Duke Energy Florida LLC, LU, 2023-01-01 2023-12-31 C001553 B. ELECTRIC UTILITY R,D&D PERFORMED EXTERNALLY, 2023-01-01 2023-12-31 C001553 170 BLUE RIDGE MOUNTAIN WOODCRAFT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1624 SOUTH MADISON, Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember McDonough-East Point 230 KV 2023-01-01 2023-12-31 C001553 FORT GORDON 2023-01-01 2023-12-31 C001553 984 LEWIS SIGN PM, Distribution, Unattended 2023-12-31 C001553 Coweta 1st Series 2006 - Variable 2023-01-01 2023-12-31 C001553 505 DORSEY TRAILERS #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 3.860% - 2044 2023-01-01 2023-12-31 C001553 1395 PREFERRED COMPOUNDING #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 569 EMORY, Distribution, Unattended 2023-12-31 C001553 688 GEORGETOWN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 422 CRYSTAL LAKE, Distribution, Unattended 2023-12-31 C001553 PLS-R Power & Light - Small 2023-01-01 2023-12-31 C001553 New Business ferc:ElectricUtilityMember 2023-12-31 C001553 DOE Loan 2.571% - 2044 2023-01-01 2023-12-31 C001553 94 AUSTELL, Distribution, Unattended 2023-12-31 C001553 1846 VALDOSTA, Distribution, Unattended 2023-12-31 C001553 30 ALCOVY ROAD, Transmission, Unattended 2023-12-31 C001553 1518 RUSSELL AREA PM Retired, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1761 THOMSON AREA #2 PM, Distribution, Unattended 2023-12-31 C001553 304 CHATHAM COUNTY INDUSTRIAL, Distribution, Unattended 2023-12-31 C001553 1169 MOUNT VERNON MILLS (Alto), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1999 WOODPECKER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 3.002% - 2044 2023-01-01 2023-12-31 C001553 1128 MILLIKEN (Kingsley Mill) Thomson, Distribution, Unattended 2023-01-01 2023-12-31 C001553 627 FLIPPEN, Distribution, Unattended 2023-12-31 C001553 Enterprise Mill, LLC, LU, 2023-01-01 2023-12-31 C001553 486 DIXIE PECAN PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1954 WHITE PM, Distribution, Unattended 2023-12-31 C001553 1409 PROPEX #3 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1766 THRALL CAR MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1476 RIVER STREET, Distribution, Unattended 2023-12-31 C001553 Georgia Power Company Rate Schedule No. 850 , ER16-2672-000 2023-01-01 2023-12-31 C001553 1560 SCOVILLE MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 789 HANSON AGGREGATES (Athens), Distribution, Unattended 2023-12-31 C001553 1625 SOUTH MCRAE, Distribution, Unattended 2023-12-31 C001553 1125 MILLHAVEN ANNEX, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1478 RIVERDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1057 MARTIN MARIETTA (Johns Creek), Distribution, Unattended 2023-12-31 C001553 588 EVANS PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 RTGSDC Real Time Pricing Day Ahead - Time of Use - General Service Demand 2023-01-01 2023-12-31 C001553 522 DUNCAN MILL ROAD, Distribution, Unattended 2023-12-31 C001553 , , , 2023-12-31 C001553 2016 YATES 6&7, Generation, Attended 2023-01-01 2023-12-31 C001553 Nuclear Financing 2023-12-31 C001553 Capital Contributions from Parent Company 2022-01-01 2022-12-31 C001553 1093 MCMANUS, Generation, Attended 2023-12-31 C001553 1750 THE ROCK, Distribution, Unattended 2023-12-31 C001553 144 BERKELEY LAKE, Distribution, Unattended 2023-12-31 C001553 315 CHICOPEE MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Effingham 1st Series 2003 - Variable 2023-12-31 C001553 525 EAGLE GRANITE, Distribution, Unattended 2023-12-31 C001553 1364 PLANTATION PIPELINE (Lafayette), Distribution, Unattended 2023-12-31 C001553 Nuclear Engineering Construction and Removal Serv., Southern Nuclear Operating Company 2023-01-01 2023-12-31 C001553 1266 OCMULGEE STREET, Distribution, Unattended 2023-12-31 C001553 Progress Payments 2023-01-01 2023-12-31 C001553 203 BOWEN, Generation, Attended 2023-12-31 C001553 879 JACK MCDONOUGH, Generation, Attended 2023-12-31 C001553 1216 NORTH JEFFERSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 877 J. T. RYERSON & SON #2, Distribution, Unattended 2023-12-31 C001553 Substation Reliability Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 469 DELTA AIRLINES #1, Distribution, Unattended 2023-12-31 C001553 774 GULFSTREAM #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1497 ROCKBRIDGE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 66 ARMSTRONG WORLD INDUSTRIES, Distribution, Unattended 2023-12-31 C001553 622 FLAV-O-RICH IRVINDALE DAIRY, Distribution, Unattended 2023-12-31 C001553 164 BLOOMFIELD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , 230, 0.2, 2023-01-01 2023-12-31 C001553 814 HAWTHORNE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Non Current Fuel Cost Recovery 2023-01-01 2023-12-31 C001553 Substation Reliability Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 Jacksonville Electric Authority, OS, 2023-01-01 2023-12-31 C001553 IKEA Atlanta, LU, 2023-01-01 2023-12-31 C001553 856 INDIAN TRACE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1855 VIDALIA, Distribution, Unattended 2023-12-31 C001553 654 FORT GORDON SOLAR (IC-387), Generation, Attended 2023-12-31 C001553 Misc GSU ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1099 MEDUSA PORTLAND CEMENT, Distribution, Unattended 2023-12-31 C001553 Marta Electric Transportation 2023-01-01 2023-12-31 C001553 Appling 1st Series 1997 - Variable 2023-01-01 2023-12-31 C001553 1406 PROPEX #10 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 359 COLEMAN, Distribution, Unattended 2023-12-31 C001553 RTPHPLLC Real Time Pricing Hour Ahead - Power & Light Large 2023-01-01 2023-12-31 C001553 1863 VISY PAPER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 56 APALACHEE AREA #1 PM (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1249 NORTHWEST PERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCDONOUGH CC #4 TIE LINE, 230, 0.83, 0 2023-01-01 2023-12-31 C001553 Bartow 2nd Series 2022 - Variable 2023-12-31 C001553 1319 PAUL WINNIE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 221 BROADWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 558 EDISON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1753 THIELE KAOLIN (Sandersville), Distribution, Unattended 2023-12-31 C001553 Burke 1st Series 2018 - Variable 2023-01-01 2023-12-31 C001553 955 KRAFT 115, Transmission, Attended 2023-12-31 C001553 1902 WALLACE DAM, Generation, Attended 2023-12-31 C001553 Commitments ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1513 ROYAL ATLANTA, Distribution, Unattended 2023-12-31 C001553 1380 PORTLAND, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Tennessee, 2022-12-31 C001553 878 J. WILLFORD PM (Vesta), Distribution, Unattended 2023-12-31 C001553 553 EATONTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 632 FOLKSTON, Distribution, Unattended 2023-12-31 C001553 Storm Damage 2023-12-31 C001553 599 FAYETTEVILLE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2001 WRENS, Distribution, Unattended 2023-12-31 C001553 1686 STOCKBRIDGE, Transmission, Unattended 2023-12-31 C001553 575 ENGINEERED FABRICS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Agent Fees 2023-01-01 2023-12-31 C001553 1211 NORTH FAIRMOUNT, Distribution, Unattended 2023-12-31 C001553 468 DELTA AIRLINES #1, Distribution, Unattended 2023-12-31 C001553 69 ASAMA COLDWATER MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 782 GWINNETT COUNTY WFP (Shoal Creek), Distribution, Unattended 2023-01-01 2023-12-31 C001553 4 ACORN CREEK PM, Distribution, Unattended 2023-12-31 C001553 Transmission Total 2023-01-01 2023-12-31 C001553 LITTLE OGEECHEE (WHITE) 230, 230, 24.38, 855216 2023-01-01 2023-12-31 C001553 1862 VIRGINIA AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 845 HOWARD #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 427 CULVERTON #3 PM, Distribution, Unattended 2023-12-31 C001553 947 KING STREET, Distribution, Unattended 2023-12-31 C001553 844 HOUSTON CHAPEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 353 COBB PLACE, Distribution, Unattended 2023-12-31 C001553 1313 PARKENSON CHURCH ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 370 COLONIAL PIPELINE (Powder Springs), Distribution, Unattended 2023-01-01 2023-12-31 C001553 340 CLYATTVILLE, Distribution, Unattended 2023-12-31 C001553 Georgia Power Company ferc:JuneMember 2023-01-01 2023-12-31 C001553 728 GOAT ROCK HYDRO, Generation, Attended 2023-12-31 C001553 Miscellaneous Transmission Line Additions & Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:GenerationSubstationMember 2023-12-31 C001553 1286 ORANGE, Distribution, Unattended 2023-12-31 C001553 WEST BRUNSWICK 230 KV LN, , , 86118 2023-01-01 2023-12-31 C001553 616 FISHING CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1453 REIDSVILLE, Distribution, Unattended 2023-12-31 C001553 1236 NORTH THOMSON, Distribution, Unattended 2023-12-31 C001553 7 ADAMS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 289 CEDAR CREEK ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 689 GEORGETOWN (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Distribution Substation Additions & Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 Plant Scherer - Outage Projects ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Fiber Optics Spurs Construction ferc:ElectricUtilityMember 2023-12-31 C001553 498 DODGE AGRICULTURAL PARK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Deferred Debits 2022-12-31 C001553 1810 TWILIGHT, Distribution, Unattended 2023-12-31 C001553 0 2023-01-01 2023-12-31 C001553 447 DAVIS STREET, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Jobs in Progress - Cost 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Mississippi, 2023-01-01 2023-12-31 C001553 111 BARTLETTS FERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1093 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 1291 OWENS CORNING FIBERGLASS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1910 WANSLEY PUMPING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1942 WEST DICKEY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1216 NORTH JEFFERSON, Distribution, Unattended 2023-12-31 C001553 PJM Interconnection, OS, T4 2023-01-01 2023-12-31 C001553 354 COBLE DAIRY PD, Distribution, Unattended 2023-12-31 C001553 1246 NORTHSIDE DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1926 WAYCROSS MOULDED PRODUCTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 739 GORDON, Transmission, Unattended 2023-12-31 C001553 341 COAL MOUNTAIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1159 MORGAN PRIMARY, Transmission, Unattended 2023-12-31 C001553 696 GEORGIA MARBLE #5 (Marble Hill), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1596 SOCIAL CIRCLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1038 MAGNOLIA PARK, Distribution, Unattended 2023-12-31 C001553 EXELON GENERATION COMPANY, LLC EXELON GENERATION COMPANY, LLC GTC LFP HILLABEE 210 2023-01-01 2023-12-31 C001553 18 ALADDIN FIBER ONE #2 PD, Distribution, Unattended 2023-12-31 C001553 Other, Net 2023-01-01 2023-12-31 C001553 1889 VULCAN MATERIALS (Norcross), Distribution, Unattended 2023-01-01 2023-12-31 C001553 FORT STEWART 2023-12-31 C001553 1170 MOUNT VERNON MILLS (Cleveland), Distribution, Unattended 2023-12-31 C001553 1177 MOUNTAIN VIEW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 445 DAVIE SLICE PM, Distribution, Unattended 2023-12-31 C001553 1594 SNAPFINGER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1536 SATILLA CREEK, Distribution, Unattended 2023-12-31 C001553 ALL SOURCE RFP DOCKET 55268 2023-01-01 2023-12-31 C001553 170 BLUE RIDGE MOUNTAIN WOODCRAFT, Distribution, Unattended 2023-12-31 C001553 446 DAVIS STREET, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1793 TRENTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 609 FIELDALE FARMS (Cornelia), Distribution, Unattended 2023-12-31 C001553 ferc:CurrentYearMember Associated Sales – Mississippi Power Company ferc:NitrogenOxideMember 2023-01-01 2023-12-31 C001553 WEST FRASER & STANDARD CONCRETE PETIT - DOCKET NOS. 43689, 43690, and 43688 2023-01-01 2023-12-31 C001553 Westar Energy, Inc., OS, T4 2023-01-01 2023-12-31 C001553 MORROW, 230, 20.18, 285883 2023-01-01 2023-12-31 C001553 392 CONYERS, Transmission, Unattended 2023-12-31 C001553 1533 SARDIS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1397 PREFERRED COMPOUNDING #4 PD, Distribution, Unattended 2023-12-31 C001553 597 FAYETTEVILLE, Distribution, Unattended 2023-12-31 C001553 1363 PLANTATION PIPELINE (Doraville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 786 HAIRSTON ROAD, Distribution, Unattended 2023-12-31 C001553 Other Accounts (Specify, provide details in footnote): 2023-01-01 2023-12-31 C001553 862 INTERNATIONAL PAPER (Gordon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 749 GRADY FLOYD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:LandAndRightsMember Northwest Region Operating HQ Site 2023-01-01 2023-12-31 C001553 1248 NORTHWEST 115, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Converged Network Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 ferc:LandAndRightsMember Medical Arts Substation Site 2023-12-31 C001553 WILSON 2023-01-01 2023-12-31 C001553 1887 VULCAN MATERIALS (Lithonia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Appling First Series 2011 - Variable 2023-01-01 2023-12-31 C001553 1760 THOMPSON BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1289 OVERLAND TRAIL LAND PM, Distribution, Unattended 2023-12-31 C001553 ferc:OtherTaxesAndFeesMember 2023-01-01 2023-12-31 C001553 1985 WIND GAP FARMS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Distribution Projects Contribution In Aid Of Construction Offset ferc:ElectricUtilityMember 2023-12-31 C001553 244 BULK FABRICATED PRODUCTS, Distribution, Unattended 2023-12-31 C001553 1045 MANSFIELD, Distribution, Unattended 2023-12-31 C001553 1291 OWENS CORNING FIBERGLASS, Distribution, Unattended 2023-12-31 C001553 642 FORREST ROAD (Macon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 221 BROADWAY, Distribution, Unattended 2023-12-31 C001553 Distribution Network Improvements - Miscellaneous ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 368 2023-01-01 2023-12-31 C001553 1891 W. L. BONNELL #1, Distribution, Unattended 2023-12-31 C001553 1714 SWEETBOTTOM, Distribution, Unattended 2023-12-31 C001553 Overstressed Or Obsolete Circuit Switcher Replacement ferc:ElectricUtilityMember 2023-12-31 C001553 ferc:Quarter2Member Georgia Power Company 2023-01-01 2023-12-31 C001553 WINDER 230 KV LN, 230, 66.37, 266473 2023-01-01 2023-12-31 C001553 1360 PLANTATION PIPELINE PM (Bio), Distribution, Unattended 2023-12-31 C001553 1466 RICHARDSON STREET, Distribution, Unattended 2023-12-31 C001553 197 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1665 SPRING STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, South Carolina, 2022-12-31 C001553 752 GRAPHIC PACKAGING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 4-6 2023-12-31 C001553 683 GARDEN CITY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1465 RICE CREEK PM, Distribution, Unattended 2023-12-31 C001553 1570 SHAW INDUSTRIES (Milledgeville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2019A - 2.20% 2023-01-01 2023-12-31 C001553 107 BANNING LAKE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 987 LIKEN INDUSTRIES, Distribution, Unattended 2023-12-31 C001553 1222 NORTH MARTIN, Distribution, Unattended 2023-12-31 C001553 Replace Failed Equipment 2023-01-01 2023-12-31 C001553 1956 WHITEHALL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1225 NORTH MILLEDGEVILLE, Distribution, Unattended 2023-12-31 C001553 Exelon Generation Company, LLC, OS, T4 2023-01-01 2023-12-31 C001553 1037 MAGNOLIA MANOR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 470 DELTA AIRLINES #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1497 ROCKBRIDGE ROAD, Distribution, Unattended 2023-12-31 C001553 Miscellaneous 2023-01-01 2023-12-31 C001553 1237 NORTH TIFTON, Transmission, Unattended 2023-12-31 C001553 865 INTERSTATE CENTRE, Distribution, Unattended 2023-12-31 C001553 1421 PULASKI SEWAGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 360 2023-01-01 2023-12-31 C001553 352 COBB PLACE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Nacoochee (A) 2023-01-01 2023-12-31 C001553 189 BOULEVARD (Atlanta), Transmission, Unattended 2023-12-31 C001553 175 BOGART, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1018 LOUISVILLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1779 TOM HUSTON PEANUT (Bakery), Distribution, Unattended 2023-01-01 2023-12-31 C001553 425 CSX TRANSPORTATION PM (Fitzgerald), Distribution, Unattended 2023-01-01 2023-12-31 C001553 SASIND Seasonal Agricultural Service 2023-01-01 2023-12-31 C001553 1180 MUD CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1023 LYLE CIRCLE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 (D) Licensed Project Number 2341. 2023-01-01 2023-12-31 C001553 1033 MAGNOLIA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1158 MORGAN FALLS HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 625 FLINT RIVER PRIMARY, Transmission, Unattended 2023-12-31 C001553 1648 SOUTHERN NATURAL GAS (Ellerslie), Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember Wallace Dam - Klondike 500 KV 2023-12-31 C001553 ferc:LandAndRightsMember New Hampstead Substation 2023-01-01 2023-12-31 C001553 1796 TRIBUTARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 ferc:PayrollTaxMember 2023-01-01 2023-12-31 C001553 1505 ROPER INDUSTRIES (RETIRED), Distribution, Unattended 2023-12-31 C001553 154 BIG POPLAR SPRINGS ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Generation Software Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 1590 SMITHVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 269 CANDLER HOSPITAL, Distribution, Unattended 2023-12-31 C001553 1162 MORNINGSIDE, Distribution, Unattended 2023-12-31 C001553 2014 YATES 6&7, Generation, Attended 2023-01-01 2023-12-31 C001553 MPC Generating, LLC, OS, 2023-01-01 2023-12-31 C001553 1278 OLD RIVER ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 263 CALHOUN COUNTY PRISON #2 PD (West), Distribution, Unattended 2023-12-31 C001553 985 LEXINGTON COMPONENTS, Distribution, Unattended 2023-12-31 C001553 Technology 2023-01-01 2023-12-31 C001553 770 GROVE POINT ROAD, Distribution, Unattended 2023-12-31 C001553 388 CONLEY CREEK, Distribution, Unattended 2023-12-31 C001553 1973 WILLOW RUN ROAD, Distribution, Unattended 2023-12-31 C001553 2022 YOUNG STATION, Distribution, Unattended 2023-12-31 C001553 NORTHWEST #1 230 KV LN, 230, 4.59, 2953689 2023-01-01 2023-12-31 C001553 261 CAGLES (Perry), Distribution, Unattended 2023-12-31 C001553 ferc:OtherProductionPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1537 SAULTER PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1913 WARRENTON AREA #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1067 MCCREE PM, Distribution, Unattended 2023-12-31 C001553 387 CONLEY CREEK, Distribution, Unattended 2023-12-31 C001553 1759 THOMASTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:SeptemberMember 2023-01-01 2023-12-31 C001553 1380 PORTLAND, Transmission, Unattended 2023-12-31 C001553 Deferred Capitalized Interest on Nuclear 2023-01-01 2023-12-31 C001553 1770 TIMBERMEN #1 (Warrenton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 SOUTH BAINBRIDGE 230 KV LN, 230, 53.4, 860609 2023-01-01 2023-12-31 C001553 BOWEN, CARTERSVILLE, Steel Tower, 795 ACSR 2023-01-01 2023-12-31 C001553 General 2023-01-01 2023-12-31 C001553 1193 NECO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 584 EUHARLEE, Distribution, Unattended 2023-12-31 C001553 MORROW 230 KV LN, 230, 11.67, 187143 2023-01-01 2023-12-31 C001553 469 DELTA AIRLINES #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 0, 2023-01-01 2023-12-31 C001553 1430 R. M. MOORE PM, Distribution, Unattended 2023-12-31 C001553 30 ALCOVY ROAD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Capital Maintenance / Asset Management ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1279 OLD SAVANAH ROAD PM, Distribution, Unattended 2023-12-31 C001553 198 BOWEN, Generation, Attended 2023-12-31 C001553 454 DAWSON PRIMARY, Transmission, Unattended 2023-12-31 C001553 1090 MCMANUS, Generation, Attended 2023-12-31 C001553 Sterling A. Spainhour 2023-01-01 2023-12-31 C001553 EAST POINT #1 230 KV LN, 230, 11.04, 6779 2023-01-01 2023-12-31 C001553 481 DIAMOND HILL AREA PM, Distribution, Unattended 2023-12-31 C001553 Non-Cumulative, Par Value $25 Per Share 2023-12-31 C001553 603 FENWICK STREET, Distribution, Unattended 2023-12-31 C001553 CBM Monitor Deployment 2023-01-01 2023-12-31 C001553 DOE Loan 2.434% - 2044 2023-12-31 C001553 1856 VIENNA PRIMARY, Transmission, Unattended 2023-12-31 C001553 372 2023-01-01 2023-12-31 C001553 855 IDLEWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BUCKHEAD, BULL SLUICE, Steel Pole, 1351 ACSR 2023-01-01 2023-12-31 C001553 1218 NORTH JEFFERSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, South Carolina, 2023-12-31 C001553 634 FOLKSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 741 GORDON ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 266 CAMP JOSEY #2 PD, Distribution, Unattended 2023-12-31 C001553 1332 PEEPLES VALLEY, Distribution, Unattended 2023-12-31 C001553 2009 WRIGHTSVILLE PRIMARY, Transmission, Unattended 2023-12-31 C001553 228 BROWN BROTHERS #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1741 TERRORA, Distribution, Unattended 2023-12-31 C001553 VOGTLE 1&2 2023-12-31 C001553 1645 SOUTHERN MILLS #2 (Senoia), Distribution, Unattended 2023-12-31 C001553 757 GREAT SOUTHWEST AMUSEMENT PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 McDonough-East Point 230 KV 2023-01-01 2023-12-31 C001553 ferc:OperatingUtilityMember 2022-12-31 C001553 1724 TALLULAH FALLS, Generation, Attended 2023-01-01 2023-12-31 C001553 1983 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 SEMINOLE ELECTRIC COOPERATIVE INCORPORATED SEMINOLE ELECTRIC COOPERATIVE INCORPORATED FPL LFP DANIEL 50 2023-01-01 2023-12-31 C001553 763 GREENVILLE, Distribution, Unattended 2023-12-31 C001553 450 DAWSON, Distribution, Unattended 2023-12-31 C001553 534 EAST EVANS, Distribution, Unattended 2023-12-31 C001553 TOUGSD-C Time of Use - General Service Demand 2023-01-01 2023-12-31 C001553 Contributions to capital by parent company 2023-01-01 2023-12-31 C001553 FUTA, Payroll Tax, 0, 2023-01-01 2023-12-31 C001553 System Operations - Study Driven - Generation Changes ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1039 MAGNOLIA ROAD PM, Distribution, Unattended 2023-12-31 C001553 128 BEAULIEU AMERICA (Royston), Distribution, Unattended 2023-12-31 C001553 1884 VULCAN MATERIALS (Columbus), Distribution, Unattended 2023-12-31 C001553 1818 TYCO PLASTICS #1, Distribution, Unattended 2023-12-31 C001553 1348 PILGRIMS PRIDE #1 (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1488 ROBINS AFB #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:OperatingReserveSpinningMember 2023-01-01 2023-12-31 C001553 Plant Retirements 2023-01-01 2023-12-31 C001553 1056 MARTIN MARIETTA (Gray), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1116 MILL CITY SEWAGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2019A - 2.20% 2023-12-31 C001553 1329 PEACHTREE CORNERS, Distribution, Unattended 2023-12-31 C001553 503 DORAVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1892 W. L. BONNELL #2, Distribution, Unattended 2023-12-31 C001553 230 KV STEEL STRUCTURES, , , 2023-01-01 2023-12-31 C001553 1148 MONROE, Distribution, Unattended 2023-12-31 C001553 15 AIRPORT ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1195 NEWELL RECYCLING #1 (East Point), Distribution, Unattended 2023-01-01 2023-12-31 C001553 853 HUTCHINSON ISLAND, Distribution, Unattended 2023-12-31 C001553 1512 ROTTENWOOD CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 754 GRAVITT, Distribution, Unattended 2023-12-31 C001553 1891 W. L. BONNELL #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 555 EATONTON PUMPING PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 723 GIBSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1071 MCDONOUGH CONSTRUCTION, Distribution, Unattended 2023-12-31 C001553 Converged Network Upgrades 2023-01-01 2023-12-31 C001553 942 KINCHAFOONEE, Distribution, Unattended 2023-12-31 C001553 658 FORTY FIFTH STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1897 WABASH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1723 TALLULAH FALLS, Generation, Attended 2023-01-01 2023-12-31 C001553 13 AIRGAS (Pendergrass), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1693 STOWE WOODWARD, Distribution, Unattended 2023-12-31 C001553 See Attachment 261.1 2023-01-01 2023-12-31 C001553 998 LITHONIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 958 LAFARGE AGGREGATES #4 PD Oxford, Distribution, Unattended 2023-12-31 C001553 596 FAIRINGTON RIDGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1678 STATESBORO AREA #8 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1566 SEVENTH AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Entergy Services, OS, T4 2023-01-01 2023-12-31 C001553 430 CUMMING, Distribution, Unattended 2023-12-31 C001553 Georgia Power Company ferc:FebruaryMember 2023-01-01 2023-12-31 C001553 43 AMERICUS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1900 WALLACE DAM, Generation, Attended 2023-01-01 2023-12-31 C001553 COVID-19 Costs 2023-12-31 C001553 704 GEORGIA PACIFIC (Sterling), Distribution, Unattended 2023-12-31 C001553 2177, OLIVER DAM 2023-12-31 C001553 1418 PROPEX #9 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1721 TALLULAH FALLS, Generation, Attended 2023-12-31 C001553 1877 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:ReactiveSupplyAndVoltageMember 2023-01-01 2023-12-31 C001553 1606 SOUTH ADEL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 693 GEORGIA IRON WORKS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1265 OCHLOCKNEE PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1529 SANDY BOTTOM, Distribution, Unattended 2023-12-31 C001553 1407 PROPEX #11 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1826 U.S. MARINE CORPS SUPPLY DEPOT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 954 KOYO BEARING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1107 MENLO, Distribution, Unattended 2023-12-31 C001553 1479 RIVERSIDE MILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1503 ROOPVILLE, Distribution, Unattended 2023-12-31 C001553 556 EATONTON RADIO STATION PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 854 IDEAL WOOD PELLETS PD, Distribution, Unattended 2023-12-31 C001553 718 GERDAU, Distribution, Unattended 2023-01-01 2023-12-31 C001553 627 FLIPPEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 81 ATLANTA WATER TREATMENT (Bolton), Distribution, Unattended 2023-12-31 C001553 586 EVANS PM, Distribution, Unattended 2023-12-31 C001553 487 DIXIE PECAN PM, Distribution, Unattended 2023-12-31 C001553 604 FERGUSON AVENUE, Transmission, Unattended 2023-01-01 2023-12-31 C001553 405 CORNELL AVENUE, Distribution, Unattended 2023-12-31 C001553 2003 WRENS, Distribution, Unattended 2023-12-31 C001553 1592 SMYRNA, Distribution, Unattended 2023-12-31 C001553 379 COMER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Purchases/Transfers:ferc:NitrogenOxideMember 2023-01-01 2023-12-31 C001553 Administrative Fees 2023-01-01 2023-06-30 C001553 409 COTTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 771 GROVE POINT ROAD, Distribution, Unattended 2023-12-31 C001553 961 LAKE JENNIFER PM, Distribution, Unattended 2023-12-31 C001553 1535 SASSER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Motor Vehicle Tag Fees, Other Taxes and Fees, 0, 2023-12-31 C001553 1471 RISING FAWN, Distribution, Unattended 2023-12-31 C001553 317 CHILDRESS PM, Distribution, Unattended 2023-12-31 C001553 1849 VARNELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1841 UNIVERSITY OF WEST GEORGIA, Distribution, Unattended 2023-12-31 C001553 1685 STILESBORO, Distribution, Unattended 2023-12-31 C001553 Deferred Income Taxes 2023-12-31 C001553 758 GREEN ACRES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1347 PILGRIMS PRIDE #1 (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1127 MILLIKEN (Duncan Stewart) Lagrange, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1865 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 523 DURHAM PARK, Distribution, Unattended 2023-12-31 C001553 778 GUM CREEK PM, Distribution, Unattended 2023-12-31 C001553 1004 LIZELLA, Distribution, Unattended 2023-12-31 C001553 1536 SATILLA CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 KGen Sandersville LLC, OS, 2023-01-01 2023-12-31 C001553 1710 SWAINSBORO PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 334 CLAYTON MARCUS PM, Distribution, Unattended 2023-12-31 C001553 1979 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 1418 PROPEX #9 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1498 ROCKMART, Distribution, Unattended 2023-12-31 C001553 (E) Licensed Project Number 2350. 2023-01-01 2023-12-31 C001553 1712 SWEET CITY PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1168 MOUNT VERNON, Distribution, Unattended 2023-12-31 C001553 1957 WHITEMARSH ISLAND, Distribution, Unattended 2023-12-31 C001553 1506 ROPERS CORNER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Storm Damage 2022-12-31 C001553 Miscellaneous Deferred Debits 2023-12-31 C001553 278 CARPENTER FLAT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1933 WESLEYAN DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 248 BURGESS PIGMENT #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1020 LUCENT TECHNOLOGIES #2 (OFS FITEL), Distribution, Unattended 2023-12-31 C001553 831 HILL STREET, Distribution, Unattended 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (1st Issuance) 2023-01-01 2023-12-31 C001553 Miscellaneous Deferred Credits 2022-12-31 C001553 PLANT BOWEN SCRUBBER TIE LINE UNIT 1 & 2, 230, 0.3, 0 2023-01-01 2023-12-31 C001553 827 HIGHWAY 106 PM (Commerce), Distribution, Unattended 2023-12-31 C001553 1324 PEACH ORCHARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Federal Income Taxes 2023, Income Tax, , 2023-12-31 C001553 941 KINCHAFOONEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 912 JONES CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1835 UNION POINT PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Flint River (B) 2023-12-31 C001553 1625 SOUTH MCRAE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 2nd Series 2009 - Variable 2023-12-31 C001553 625 FLINT RIVER PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1936 WEST ATHENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1000 LITHONIA LIGHTING, Distribution, Unattended 2023-12-31 C001553 1438 RAY MOUNTAIN 2 PM, Distribution, Unattended 2023-12-31 C001553 Piedmont Forrest Corporation ferc:AdvancesOpenAccountMember 2023-01-01 2023-12-31 C001553 590 EVERGREEN, Distribution, Unattended 2023-12-31 C001553 1830 U.S. VETERANS HOSPITAL (Dublin), Distribution, Unattended 2023-01-01 2023-12-31 C001553 , 69, 83.54, 1608856 2023-01-01 2023-12-31 C001553 Doraville Balance of Substation Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 Gas and Electric Hedges 2023-12-31 C001553 Net Worth, Other License And Fees Tax, Georgia, 2023-12-31 C001553 243 BUHLER QUALITY YARNS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1562 SEA ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Nuclear Decommissioning 2022-12-31 C001553 628 FLIPPEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 713 GEORGIA SYNTHETICS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1015 LOOKOUT VALLEY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 570 EMORY, Distribution, Unattended 2023-12-31 C001553 200 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 245 BULL CREEK, Distribution, Unattended 2023-12-31 C001553 DOE Loan 2.434% - 2044 2023-01-01 2023-12-31 C001553 145 BETHLEHEM 115/25-KV, Distribution, Unattended 2023-01-01 2023-12-31 C001553 525 EAGLE GRANITE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 130 BEAVER DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Deferred Plant Depreciation 2023-01-01 2023-12-31 C001553 Mercuria Energy America, Inc, LU, 2023-01-01 2023-12-31 C001553 1910 WANSLEY PUMPING, Distribution, Unattended 2023-12-31 C001553 1059 MARTIN MARIETTA (Martinez), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Administrative Fees 2023-01-01 2023-09-30 C001553 1073 MCINTOSH, Transmission, Unattended 2023-12-31 C001553 ferc:SulfurDioxideMember Allowances Used 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember 2023-12-31 C001553 579 ERCO WORLDWIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 2nd Series 2012 - 1.70% 2023-12-31 C001553 802 HATCH, Generation, Attended 2023-12-31 C001553 530 EAST BAINBRIDGE, Distribution, Unattended 2023-12-31 C001553 1930 WELCOME ALL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1116 MILL CITY SEWAGE PM, Distribution, Unattended 2023-12-31 C001553 154 BIG POPLAR SPRINGS ROAD PM, Distribution, Unattended 2023-12-31 C001553 702 GEORGIA PACIFIC (Ellabell), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1650 SOUTHERN RAILWAY, Distribution, Unattended 2023-12-31 C001553 1814 TWIN PINES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Cumulative Preferred, Par Value $100 Per Share 2023-01-01 2023-12-31 C001553 1177 MOUNTAIN VIEW, Distribution, Unattended 2023-12-31 C001553 Funding Collateral 2022-12-31 C001553 638 FORREST LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WABASH-BOULEVARD 230 KV LN, 230, 3.38, 707 2023-01-01 2023-12-31 C001553 148 BICKERSTAFF CLAY PRODUCTS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 281 CARWOOD MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1455 REMLERS CORNER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1539 SCHERER COMMON FACILITIES, Generation, Attended 2023-01-01 2023-12-31 C001553 318 CHINA HILL ROAD PM, Distribution, Unattended 2023-12-31 C001553 330 CLARKSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1333 PELHAM, Distribution, Unattended 2023-12-31 C001553 1513 ROYAL ATLANTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 153 BIG POPLAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 369 2023-01-01 2023-12-31 C001553 Burke 1st Series 2008 - Variable 2023-01-01 2023-12-31 C001553 743 GOSHEN (Savannah), Distribution, Unattended 2023-12-31 C001553 136 BELVEDERE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Transformer Replacement ferc:ElectricUtilityMember 2023-12-31 C001553 , Research Administration 566 2023-01-01 2023-12-31 C001553 1036 MAGNOLIA MANOR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 150 BIG CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 675 GAINER COTTON GIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 159 BLACKSMITH, Transmission, Unattended 2023-12-31 C001553 295 CELANESE, Transmission, Unattended 2023-12-31 C001553 1920 WATKINS WOODS PM, Distribution, Unattended 2023-12-31 C001553 10 AINSLIE PM, Distribution, Unattended 2023-12-31 C001553 OCEE, 230, 5.46, 104611 2023-01-01 2023-12-31 C001553 1764 THOMSON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 309 CHEROKEE BRICK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Building Additions & Improvements 2023-01-01 2023-12-31 C001553 1372 PONCE DE LEON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1444 RED DOG FARM ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PJM OS 2023-01-01 2023-12-31 C001553 91 AUGUSTA NEWSPRINT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Basis Differences - 109 ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1069 MCDONOUGH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 350 2023-01-01 2023-12-31 C001553 1179 MRS. SMITHS BAKERIES, Distribution, Unattended 2023-12-31 C001553 587 EVANS CLAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 732 GODLEY TRACT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Administrative and General Services, Southern Company Services 2023-01-01 2023-12-31 C001553 445 DAVIE SLICE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1532 SAPA EXTRUDER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 920 KAMIN (Wrens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1671 STANDRIDGE COLOR #18 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 959 LAGRANGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1589 SMITHVILLE, Distribution, Unattended 2023-12-31 C001553 1939 WEST DALLAS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1446 RED TOP MOUNTAIN, Distribution, Unattended 2023-12-31 C001553 605 FIELDALE (Cornelia), Distribution, Unattended 2023-12-31 C001553 279 CARROLLTON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1447 REDMOND CIRCLE, Distribution, Unattended 2023-12-31 C001553 887 JACK MCDONOUGH CC #5, Generation, Attended 2023-01-01 2023-12-31 C001553 1545 SCHERER RIVER PUMPING, Distribution, Attended 2023-01-01 2023-12-31 C001553 ferc:PayrollTaxMember 2023-12-31 C001553 839 HOLLY SPRINGS, Distribution, Unattended 2023-12-31 C001553 2000 WOODVALLEY, Distribution, Unattended 2023-12-31 C001553 1154 MORELAND AVENUE, Distribution, Unattended 2023-12-31 C001553 1894 W. M. WRIGLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1155 MORELAND WAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 697 GEORGIA MARBLE (Marble Hill), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1049 MARK EVANS PM, Distribution, Unattended 2023-12-31 C001553 DEAN FOREST 230KV , 230, 4, 0 2023-01-01 2023-12-31 C001553 169 BLUE CIRCLE AGGREGATES #1 (Lithonia), Distribution, Unattended 2023-12-31 C001553 508 DOUBLE BRIDGES ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 937 KIMBALL BRIDGE, Distribution, Unattended 2023-12-31 C001553 1212 NORTH FORK, Distribution, Unattended 2023-12-31 C001553 1741 TERRORA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 715 GEORGIA TECH RESEARCH (Cobb), Distribution, Unattended 2023-12-31 C001553 1694 STUBBS ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1304 PACTIV #7, Distribution, Unattended 2023-12-31 C001553 120 BATH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 448 DAVISBORO PD, Distribution, Unattended 2023-12-31 C001553 1774 TNS MILLS, Distribution, Unattended 2023-12-31 C001553 889 JACK MCDONOUGH CC #6, Generation, Attended 2023-12-31 C001553 326 CITGO, Distribution, Unattended 2023-12-31 C001553 737 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1491 ROBINS AFB #4 - W.D. Fowler, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1831 U.S. VETERANS HOSPITAL (Dublin), Distribution, Unattended 2023-12-31 C001553 1833 UNIMIN, Distribution, Unattended 2023-12-31 C001553 1374 POOLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1283 OLIVER ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1857 VIENNA PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 67 ARMUCHEE, Distribution, Unattended 2023-12-31 C001553 1137 MINOLA DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:FranchiseTaxMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1831 U.S. VETERANS HOSPITAL (Dublin), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1664 SPIVEY LAKE, Distribution, Unattended 2023-12-31 C001553 37 ALTAMAHA BOULEVARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 338 CLOUDLAND CANYON, Distribution, Unattended 2023-12-31 C001553 146 BEULAH PM, Distribution, Unattended 2023-12-31 C001553 Southern Electric Generating Co. (3rd Issuance)ferc:CaptialStockMember 2022-12-31 C001553 895 JEFFERSONVILLE, Distribution, Unattended 2023-12-31 C001553 971 LAKELAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Cash Surrender Value Insurance (a) 2022-12-31 C001553 Generating Plant Outage Costs 2022-12-31 C001553 623 FLEMING, Distribution, Unattended 2023-12-31 C001553 DOE Loan Guarantee Fees and Compliance Cost 2023-01-01 2023-12-31 C001553 1472 RITE AID (Newnan), Distribution, Unattended 2023-12-31 C001553 Burke 1st Series 2013 - 2.93% 2023-01-01 2023-12-31 C001553 1045 MANSFIELD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1882 VOGTLE 3&4 500KV, Generation, Attended 2023-12-31 C001553 Software & Cloud Computing 2023-12-31 C001553 Washington County Power, LLC (Mackinaw Power), OS, T5 2023-01-01 2023-12-31 C001553 None ferc:TransmissionStudiesMember 2023-01-01 2023-12-31 C001553 1158 MORGAN FALLS HYDRO, Generation, Attended 2023-12-31 C001553 1302 PACTIV #4 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 566 2023-01-01 2023-12-31 C001553 Series 2023A - 4.65% 2023-01-01 2023-12-31 C001553 Credit Line Fees (b) 2023-12-31 C001553 535 EAST EVANS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1687 STOCKBRIDGE, Transmission, Unattended 2023-12-31 C001553 122 BAXLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 436 DAHLONEGA PRIMARY, Distribution, Unattended 2023-12-31 C001553 Gas MCINTOSH (CT) 2023-01-01 2023-12-31 C001553 75 ATHENS, Transmission, Unattended 2023-12-31 C001553 1718 TALLAPOOSA, Distribution, Unattended 2023-12-31 C001553 822 HERITAGE HILLS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 526 EAST AMERICUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1105 MELDRIM, Transmission, Unattended 2023-12-31 C001553 1230 NORTH SHALLOWFORD ROAD, Distribution, Unattended 2023-12-31 C001553 86 ATTAPULGUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1670 STANDRIDGE COLOR #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 d. Nuclear, Advanced Nuclear 2023-01-01 2023-12-31 C001553 588 EVANS PRIMARY, Transmission, Unattended 2023-12-31 C001553 1936 WEST ATHENS, Distribution, Unattended 2023-12-31 C001553 783 GWINNETT STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1247 NORTHWEST 115, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Rayonier Inc, LU, 2023-01-01 2023-12-31 C001553 466 DEKALB COUNTY WATER (Holcombe Bridge), Distribution, Unattended 2023-01-01 2023-12-31 C001553 FINANCING AUTHORITY APPLICATION - DOCKET NO. 44054 2023-12-31 C001553 465 DEKALB COUNTY SEWAGE (Snapfinger Rd), Distribution, Unattended 2023-12-31 C001553 825 HIGHTOWER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 871 J. C. PENNEY, Distribution, Unattended 2023-12-31 C001553 1517 RUCKER BROTHERS PM, Distribution, Unattended 2023-12-31 C001553 , Environmental Controls Technologies 566 2023-01-01 2023-12-31 C001553 ferc:OtherTaxesAndFeesMember 2023-12-31 C001553 NORCROSS 230 KV LN, 230, 0.26, 4981 2023-01-01 2023-12-31 C001553 716 GEORGIA TUBING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PINSON-ATLANTIC STEEL 230 K, 230, 19.77, 298850 2023-01-01 2023-12-31 C001553 493 DIXIE PIPELINE (Putney), Distribution, Unattended 2023-01-01 2023-12-31 C001553 759 GREENBRIAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1367 PLANTATION ROAD, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember 2022-01-01 2022-12-31 C001553 609 FIELDALE FARMS (Cornelia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 657 FORT STEWART SOLAR (IC-385), Generation, Attended 2023-01-01 2023-12-31 C001553 1212 NORTH FORK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Deferred Income Taxes 2023-12-31 C001553 1682 STATHAM, Distribution, Unattended 2023-12-31 C001553 1802 TROUP CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1051 MARK GLASS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1719 TALLAPOOSA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1622 SOUTH MACON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1223 NORTH MCRAE, Distribution, Unattended 2023-12-31 C001553 230 KV WOOD STRUCTURES, , , 2023-01-01 2023-12-31 C001553 96 AUSTIN DRIVE, Distribution, Unattended 2023-12-31 C001553 920 KAMIN (Wrens), Distribution, Unattended 2023-12-31 C001553 203 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 Gas MCDONOUGH NO. 4-6 2023-01-01 2023-12-31 C001553 932 KERRY #4 PD, Distribution, Unattended 2023-12-31 C001553 92 AUSTELL, Distribution, Unattended 2023-12-31 C001553 429 CUMMING, Distribution, Unattended 2023-12-31 C001553 1287 ORANGE HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 24 ALADDIN MILLS #2, Distribution, Unattended 2023-12-31 C001553 519 DUM JON, Transmission, Unattended 2023-12-31 C001553 1251 NORTHWEST WAYCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1894 W. M. WRIGLEY, Distribution, Unattended 2023-12-31 C001553 1887 VULCAN MATERIALS (Lithonia), Distribution, Unattended 2023-12-31 C001553 342 COATS AMERICAN (Toccoa), Distribution, Unattended 2023-12-31 C001553 787 HAMILTON CROSSING ROAD, Distribution, Unattended 2023-12-31 C001553 Tampa Electric Company, OS, 2023-01-01 2023-12-31 C001553 State Income Tax, Income Tax, Georgia, 2022-12-31 C001553 MCGRAU FORD 230 KV LN, 230, 35.67, 13803110 2023-01-01 2023-12-31 C001553 378 COLUMBUS SQUARE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1254 NOWHERE ROAD PM, Distribution, Unattended 2023-12-31 C001553 635 FOREST PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 754 GRAVITT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1143 MOHAWK INDUSTRIES (Lyerly), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Capital Maintenance / Asset Management 2023-01-01 2023-12-31 C001553 179 BOLLING ROAD, Distribution, Unattended 2023-12-31 C001553 514 DSM CHEMICALS, Distribution, Unattended 2023-12-31 C001553 904 JIMMY CARGILL PM, Distribution, Unattended 2023-12-31 C001553 1755 THIELE KAOLIN (Wrens), Distribution, Unattended 2023-12-31 C001553 1331 PEEPLES VALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 790 HAPEVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 557 ECHECONNEE, Distribution, Unattended 2023-12-31 C001553 1205 NORTH CLARKESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTDFPAI RTP Day Ahead - Fixed Pricing Alternative 2023-01-01 2023-12-31 C001553 1836 UNION POINT PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 561 ELLAVILLE, Distribution, Unattended 2023-12-31 C001553 524 DUTCHTOWN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 817 HAZLEHURST PRIMARY, Transmission, Unattended 2023-12-31 C001553 1379 PORTERDALE PRIMARY, Distribution, Unattended 2023-12-31 C001553 Mercuria Energy America, Inc, OS, T4 2023-01-01 2023-12-31 C001553 Clyde C. Tuggle 2023-01-01 2023-12-31 C001553 956 L. L. BARNES PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1327 PEACHTREE CITY #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 360 COLEMAN (Savannah), Distribution, Unattended 2023-12-31 C001553 1314 PARKENSON CHURCH ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1993 WINN DIXIE (Atlanta), Distribution, Unattended 2023-12-31 C001553 ferc:IncomeTaxMember 2022-12-31 C001553 163 BLEYLE AMERICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 644 FORT BENNING, Transmission, Unattended 2023-12-31 C001553 Jobs in Progress - Cost 2022-12-31 C001553 MOODY AFB 2023-12-31 C001553 550 EATONTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1067 MCCREE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1557 SCOTT HUDGENS BUILDING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:EquityContributionMember 2022-12-31 C001553 Franchise Fees - 2022, Franchise Tax, Georgia, 2023-12-31 C001553 (B) Licensed Project Number 1218. 2023-01-01 2023-12-31 C001553 719 GERDAU, Distribution, Unattended 2023-12-31 C001553 1801 TROUP CREEK, Distribution, Unattended 2023-12-31 C001553 Dominion Energy OS 2023-01-01 2023-12-31 C001553 1991 WINDY HILL, Distribution, Unattended 2023-12-31 C001553 422 CRYSTAL LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 765 GREENWOOD PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Gas WARNER ROBINS 2023-01-01 2023-12-31 C001553 698 GEORGIA MARBLE (Tate), Distribution, Unattended 2023-12-31 C001553 1463 REYNOLDS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 698 GEORGIA MARBLE (Tate), Distribution, Unattended 2023-01-01 2023-12-31 C001553 270 CANNONGATE ACRES PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1144 MOHAWK INDUSTRIES (Summerville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1219 NORTH KEITHSBURG, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BONAIRE 230 KV LN, 230, 9.93, 17918 2023-01-01 2023-12-31 C001553 1118 MILLEDGEVILLE, Distribution, Unattended 2023-12-31 C001553 Converged Network Upgrades ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Andrew W. Evans 2023-01-01 2023-12-31 C001553 Material Services, Southern Company Services 2023-01-01 2023-12-31 C001553 1701 SUNSHINE BISCUIT (Columbus), Distribution, Unattended 2023-12-31 C001553 303 CHARLES WHITLOCK PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTPGOVC Real Time Pricing Day Ahead - Governmental 2023-01-01 2023-12-31 C001553 PLS-C Power & Light - Small 2023-01-01 2023-12-31 C001553 562 ELLENWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 209 BOWMAN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Joint Owner Other Deferred Billings 2023-12-31 C001553 96 AUSTIN DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 411 COVINGTON INDUSTRIAL, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Other Non-Operating Expenses 2023-01-01 2023-12-31 C001553 Grid Modernization ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 731 GODFREY ROAD PM, Distribution, Unattended 2023-12-31 C001553 OL-UN Outdoor Lighting 2023-01-01 2023-12-31 C001553 1075 MCINTOSH CC, Generation, Attended 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 3 Gas 2023-01-01 2023-12-31 C001553 1644 SOUTHERN MILLS #1 (Senoia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 2.537% - 2044 2 2023-12-31 C001553 City of Robertsdale City of Robertsdale City of Robertsdale FNO N/A 13 2023-01-01 2023-12-31 C001553 182 BOLTON STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1774 TNS MILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 457 DEAN STEEL BUILDINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 242 BUFORD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricPlantInServiceMember 2023-01-01 2023-12-31 C001553 1262 OAKEY WOODS PM, Distribution, Unattended 2023-12-31 C001553 Floyd 1st Series 1996 - Variable 2023-12-31 C001553 1273 OLD ALABAMA ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1434 RAINBOW DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1560 SCOVILLE MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1402 PROCTER & GAMBLE (Albany), Distribution, Unattended 2023-12-31 C001553 1803 TROY ALDRIDGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 335 CLEARWATER ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1148 MONROE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PLM-C Power & Light - Medium 2023-01-01 2023-12-31 C001553 1688 STOCKBRIDGE, Transmission, Unattended 2023-12-31 C001553 440 DAMES FERRY, Distribution, Unattended 2023-12-31 C001553 543 EAST VALDOSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Solar Self Build Projects 2023-01-01 2023-12-31 C001553 528 EAST AUGUSTA, Distribution, Unattended 2023-12-31 C001553 Miscellaneous Minor Projects (Less Than $1 Million)ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1776 TODD MARSHALL PM, Distribution, Unattended 2023-12-31 C001553 CWIP Electric 2023-01-01 2023-12-31 C001553 708 GEORGIA PACIFIC SAWMILL (Albany), Distribution, Unattended 2023-12-31 C001553 668 FRUIT OF THE LOOM (Dillard), Distribution, Unattended 2023-12-31 C001553 733 GOLD MINE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 External Decommissioning 2023-01-01 2023-12-31 C001553 1420 PULASKI, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1340 PETERSBURG ROAD, Distribution, Unattended 2023-12-31 C001553 1189 NASHVILLE MILLS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 910 2023-01-01 2023-12-31 C001553 45 ANCHOR GLASS, Distribution, Unattended 2023-12-31 C001553 773 GUARDIAN AUTOMOTIVE #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 28 ALAPAHA, Distribution, Unattended 2023-12-31 C001553 1000 LITHONIA LIGHTING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 632 FOLKSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 PORTERDALE, 230, 53.01, 750975 2023-01-01 2023-12-31 C001553 Plant Vogtle 1&2 - Controls ferc:ElectricUtilityMember 2023-12-31 C001553 93 AUSTELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 739 GORDON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1276 OLD MAUK ROAD, Distribution, Unattended 2023-12-31 C001553 1848 VARNELL, Distribution, Unattended 2023-12-31 C001553 1183 MULLITE #2, Distribution, Unattended 2023-12-31 C001553 759 GREENBRIAR, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricUtilityMember Plant McIntosh - Miscellaneous Additions 2023-12-31 C001553 138 BELVEDERE, Distribution, Unattended 2023-12-31 C001553 1189 NASHVILLE MILLS ROAD, Distribution, Unattended 2023-12-31 C001553 688 GEORGETOWN, Distribution, Unattended 2023-12-31 C001553 1997 WOODBURY, Distribution, Unattended 2023-12-31 C001553 Bird Dog Solar LLC, OS, 2023-01-01 2023-12-31 C001553 1372 PONCE DE LEON, Distribution, Unattended 2023-12-31 C001553 1052 MARSHALLVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 922 KAOLIN, Transmission, Unattended 2023-12-31 C001553 KETTLE CREEK 230 KV, 230, 37.13, 1635888 2023-01-01 2023-12-31 C001553 670 FURNACE ROAD, Distribution, Unattended 2023-12-31 C001553 678 GAINESVILLE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NonUtilityMember CWIP NonElectric 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 524 2023-01-01 2023-12-31 C001553 758 GREEN ACRES, Distribution, Unattended 2023-12-31 C001553 78 ATHENS PUMPING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1792 TRENTON, Distribution, Unattended 2023-12-31 C001553 939 KIMBALL BRIDGE, Distribution, Unattended 2023-12-31 C001553 656 FORT STEWART, Distribution, Unattended 2023-12-31 C001553 1744 TEXAS VALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1341 PETERSON CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1246 NORTHSIDE DRIVE, Distribution, Unattended 2023-12-31 C001553 1738 TEMPLE INDUSTRIES (Thomson), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1746 THALMANN, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1623 SOUTH MADISON, Distribution, Unattended 2023-12-31 C001553 Deferred Affiliate Taxes Payable 2023-12-31 C001553 None, , 2023-01-01 2023-12-31 C001553 Additional Pension Deduction ferc:ElectricUtilityMember 2022-12-31 C001553 Directors' Fees and Expenses 2023-01-01 2023-12-31 C001553 1789 TRENT TUBE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 TRIBUTARY 230KV, 230, 2.8, 1796263 2023-01-01 2023-12-31 C001553 Unassigned ferc:ElectricUtilityMember 2023-12-31 C001553 131 BEAVERS ROAD PM, Distribution, Unattended 2023-12-31 C001553 360 COLEMAN (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Albany Renewable Energy, LLC, LU, 2023-01-01 2023-12-31 C001553 Power Delivery Software Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 1504 ROPER INDUSTRIES #2 (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 254 BUTLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 725 GLENNVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 800 HARTWELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1954 WHITE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 227 BROWN AND WILLIAMSON TOBACCO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1801 TROUP CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1662 SPARTA #2, Distribution, Unattended 2023-12-31 C001553 1945 WEST END, Distribution, Unattended 2023-01-01 2023-12-31 C001553 819 HEMPHILL WATER TREATMENT, Distribution, Unattended 2023-12-31 C001553 1775 TOCCOA, Distribution, Unattended 2023-12-31 C001553 669 FULGHUM FIBRES PD (Dewy Rose), Distribution, Unattended 2023-01-01 2023-12-31 C001553 95 AUSTELL BOX BOARD, Distribution, Unattended 2023-12-31 C001553 542 EAST VALDOSTA, Distribution, Unattended 2023-12-31 C001553 380 COMER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1793 TRENTON, Distribution, Unattended 2023-12-31 C001553 Nuclear HATCH 2023-01-01 2023-12-31 C001553 1409 PROPEX #3 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 537 EAST LUMPKIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1864 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 723 GIBSON, Distribution, Unattended 2023-12-31 C001553 935 KIA MOTORS, Distribution, Unattended 2023-12-31 C001553 1053 MARTA ANNEX, Distribution, Unattended 2023-12-31 C001553 DOE Loan 2.571% - 2044 2023-12-31 C001553 1982 WILSON, Generation, Attended 2023-12-31 C001553 2354, TUGALO 2023-01-01 2023-12-31 C001553 1956 WHITEHALL, Distribution, Unattended 2023-12-31 C001553 119 BASSETT FURNITURE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 OL-UN Outdoor Lighitng 2023-01-01 2023-12-31 C001553 874 J. M. HUBER MINE #1 (Marble Hill) PM, Distribution, Unattended 2023-12-31 C001553 1599 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 VARIOUS Tariff Customers VARIOUS Tariff Customers VARIOUS OS VARIOUS 0 2023-01-01 2023-12-31 C001553 1698 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 Southern Electric Generating Co, OS, 2023-01-01 2023-12-31 C001553 Distribution Services (e) 2022-12-31 C001553 SMYRNA 230 KV, 230, 6.93, 4616729 2023-01-01 2023-12-31 C001553 1842 UNIVETER CROSSING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 356 2023-01-01 2023-12-31 C001553 Gas and Electric Hedges 2022-12-31 C001553 92 AUSTELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 GRADY 230 KV LN, 230, , 0 2023-01-01 2023-12-31 C001553 151 BIG CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-12-31 C001553 1371 PONCE DE LEON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Community Development 2023-01-01 2023-12-31 C001553 750 GRAHAM PACKAGING #5 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Alabama Municipal Electric Authority Alabama Municipal Electric Authority Alabama Municipal Electric Authority FNO N/A 470 2023-01-01 2023-12-31 C001553 88 AUGUSTA AREA #1 PM, Distribution, Unattended 2023-12-31 C001553 238 BUENA VISTA, Distribution, Unattended 2023-12-31 C001553 1156 MORGAN FALLS, Distribution, Unattended 2023-12-31 C001553 866 INTERSTATE PAPER, Distribution, Unattended 2023-12-31 C001553 1072 MCGRAU FORD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 OLD ALABAMA RD 230 KV LN, 230, 2.95, 1204520 2023-01-01 2023-12-31 C001553 1461 REST HAVEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1757 THOMASTON, Distribution, Unattended 2023-12-31 C001553 482 DILLARD PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Clayton County, LU, 2023-01-01 2023-12-31 C001553 1633 SOUTH VILLA RICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 858 INDUSTRIAL PARK DRIVE, Distribution, Unattended 2023-12-31 C001553 944 KING SPRINGS ROAD, Distribution, Unattended 2023-12-31 C001553 107 BANNING LAKE PM, Distribution, Unattended 2023-12-31 C001553 828 HIGHWAY 16 PM (Eatonton), Distribution, Unattended 2023-12-31 C001553 1175 MOUNTAIN VIEW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1781 TOTAL SYSTEM SERVICES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1061 MARTIN MARIETTA (Warrenton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1016 LOUISVILLE AREA #3 PM, Distribution, Unattended 2023-12-31 C001553 1502 ROME, Distribution, Unattended 2023-12-31 C001553 433 CYPRESS POINT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1515 ROYSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1996 WOODBINE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1577 SHURLING DRIVE, Distribution, Unattended 2023-12-31 C001553 1456 REMLERS CORNER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Business License, Other License And Fees Tax, Alabama, 2022-12-31 C001553 CWIP NonElectric 2023-01-01 2023-12-31 C001553 1414 PROPEX #5 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Reserve for Future Capital Spend 2023-01-01 2023-12-31 C001553 213 BRADLEY INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 938 KIMBALL BRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1415 PROPEX #6 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NonUtilityMember CWIP NonElectric 2023-12-31 C001553 1649 SOUTHERN NATURAL GAS (Fairburn), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Prepaid Rent for Outdoor Lighting (c) 2023-01-01 2023-12-31 C001553 897 JEKYLL ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1351 PILGRIMS PRIDE (Canton), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1756 THIELE KAOLIN (Wrens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 417 CROOKED RIVER, Distribution, Unattended 2023-12-31 C001553 338 CLOUDLAND CANYON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 261 CAGLES (Perry), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ALL SOURCE RFP DOCKET 55268 2023-12-31 C001553 437 DAHLONEGA PRIMARY, Distribution, Unattended 2023-12-31 C001553 131 BEAVERS ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1151 MONTEZUMA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1227 NORTH OCONEE WRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Workforce Reduction Programs 2022-12-31 C001553 661 FOWLER STREET, Distribution, Unattended 2023-12-31 C001553 Nuclear Decommissioning 2022-12-31 C001553 IOP-I Irrigation Off-Peak 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:Quarter4Member 2023-01-01 2023-12-31 C001553 General Total 2023-01-01 2023-12-31 C001553 276 CARMEUSE MINE #1 PD, Distribution, Unattended 2023-12-31 C001553 76 ATHENS OPERATING PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1302 PACTIV #4 PD, Distribution, Unattended 2023-12-31 C001553 694 GEORGIA MARBLE #2 (Whitestone), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1821 TYCO PLASTICS #8, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1486 ROBERTS ROAD, Distribution, Unattended 2023-12-31 C001553 1969 WILLINGHAM DRIVE, Distribution, Unattended 2023-12-31 C001553 HATCH SAT 1E SERVICE 230KV LINE, 230, 0.23, 0 2023-01-01 2023-12-31 C001553 1208 NORTH DRUID HILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Administrative Fees 2023-01-01 2023-12-31 C001553 534 EAST EVANS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1330 PEARSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 100 BAINBRIDGE, Distribution, Unattended 2023-12-31 C001553 1146 MOLENA PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Customer Service Operations Cyber Security ferc:ElectricUtilityMember 2023-12-31 C001553 2008 WRIGHTSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 TOUSCI Time of Use Supplier Choice 2023-01-01 2023-12-31 C001553 FICA-COVID 19 State, Payroll Tax, 0, 2023-01-01 2023-12-31 C001553 GOSHEN 230KV LN, 230, 6.61, 0 2023-01-01 2023-12-31 C001553 ferc:SteamProductionPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 82 ATLANTA WATER TREATMENT (Bolton), Distribution, Unattended 2023-12-31 C001553 905 JOHNS CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Progress Payments 2022-12-31 C001553 1172 MOUNT ZION, Distribution, Unattended 2023-12-31 C001553 1223 NORTH MCRAE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1593 SMYRNA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1361 PLANTATION PIPELINE (Austell), Distribution, Unattended 2023-12-31 C001553 576 ENGLISHVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Florida Power & Light Company, OS, 2023-01-01 2023-12-31 C001553 98 AVONDALE MILL ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 623 FLEMING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2354, TUGALO 2023-12-31 C001553 1819 TYCO PLASTICS #11 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1896 WABASH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Pooled Equipment Inventory Operating 2023-01-01 2023-12-31 C001553 510 DOUBLEGATE, Distribution, Unattended 2023-12-31 C001553 Workforce Reduction Programs 2023-01-01 2023-12-31 C001553 1540 SCHERER CONSTRUCTION, Distribution, Attended 2023-01-01 2023-12-31 C001553 1845 UVALDA, Distribution, Unattended 2023-12-31 C001553 1422 PURCELL ROAD, Distribution, Unattended 2023-12-31 C001553 1804 TRUMAN PARKWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1981 WILSON, Generation, Attended 2023-12-31 C001553 581 ETHICON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1607 SOUTH ATHENS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1523 SAINT SIMONS, Distribution, Unattended 2023-12-31 C001553 1709 SWAINSBORO AREA #5 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1811 TWIN CITY, Distribution, Unattended 2023-12-31 C001553 See Attachment 261.1 2023-01-01 2023-12-31 C001553 1317 PATRIOTS PARK, Distribution, Unattended 2023-12-31 C001553 THOMSON , VOGTLE 500 KV LINE, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 Asset Retirement Obligations 2023-12-31 C001553 923 KAOLIN, Transmission, Unattended 2023-01-01 2023-12-31 C001553 215 BRIAR VISTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1851 VERDERY STREET, Distribution, Unattended 2023-12-31 C001553 1917 WARRENTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 64 ARLINGTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 669 FULGHUM FIBRES PD (Dewy Rose), Distribution, Unattended 2023-12-31 C001553 Constellation Energy, OS, T5 2023-01-01 2023-12-31 C001553 166 BLOOMINGDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 135 BELLEVUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 745 GOUGH CITY, Distribution, Unattended 2023-12-31 C001553 361 COLEMAN (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:PropertyTaxMember 2023-01-01 2023-12-31 C001553 1400 PRINGLE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 418 CROOKED RIVER, Distribution, Unattended 2023-12-31 C001553 1871 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 80 ATLANTA WATER STORAGE (Lois Street), Distribution, Unattended 2023-12-31 C001553 328 CLARKESVILLE, Distribution, Unattended 2023-12-31 C001553 1668 SPRINGFIELD, Distribution, Unattended 2023-12-31 C001553 Cost Based Rate Tariff,Southern’s Tariff Volume No. 11, ER10-2925-000 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:PaidInCapitalMember 2023-01-01 2023-12-31 C001553 585 EUREKA, Distribution, Unattended 2023-12-31 C001553 652 FORT GORDON #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1957 WHITEMARSH ISLAND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Sales Commissions (d) 2023-01-01 2023-12-31 C001553 ferc:NonUtilityMember Other Income and Deductions 2023-01-01 2023-12-31 C001553 271 CANON, Distribution, Unattended 2023-12-31 C001553 OGS-I Optional General Service 2023-01-01 2023-12-31 C001553 FICA-COVID 19 Federal, Payroll Tax, 0, 2023-12-31 C001553 150 BIG CREEK SEWAGE TREATMENT, Distribution, Unattended 2023-12-31 C001553 Pooled Equipment Inventory Operating 2023-12-31 C001553 Jacksonville Electric Authority, OS, T4 2023-01-01 2023-12-31 C001553 Additional Pension Deduction ferc:ElectricUtilityMember 2023-12-31 C001553 1464 RHINE, Distribution, Unattended 2023-12-31 C001553 361 COLEMAN (Savannah), Distribution, Unattended 2023-12-31 C001553 Reliability 2023-01-01 2023-12-31 C001553 448 DAVISBORO PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1204 NORTH AWRF, Distribution, Unattended 2023-12-31 C001553 567 ELLIJAY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 833 HINESVILLE PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1413 PROPEX #5 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 943 KING AMERICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1004 LIZELLA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 211 BOYD PM, Distribution, Unattended 2023-12-31 C001553 595 FAIR ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2022, Property Tax, Georgia,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 22 ALADDIN MILLS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1868 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 2009 WRIGHTSVILLE PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1085 MCMANUS, Generation, Attended 2023-12-31 C001553 1247 NORTHWEST 115, Distribution, Unattended 2023-12-31 C001553 POWERSOUTH ENERGY COOPERATIVE POWERSOUTH ENERGY COOPERATIVE FPLNW LFP MILLER 142 2023-01-01 2023-12-31 C001553 1404 PROPEX #1 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1998 WOODGRAIN MILLWORK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 SCHERER Oil 2023-01-01 2023-12-31 C001553 811 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 801 HARTWELL SERIES REACTOR, Transmission, Unattended 2023-01-01 2023-12-31 C001553 917 JUNCTION CITY MINING #3 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:Quarter1Member 2023-01-01 2023-12-31 C001553 1990 WINDY HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 North Georgia Hydro Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 Hydro: 2023-01-01 2023-12-31 C001553 Plant Retirements 2023-12-31 C001553 949 KINGSLAND, Distribution, Unattended 2023-12-31 C001553 260 CAGLES (Perry), Distribution, Unattended 2023-12-31 C001553 Miscellaneous 2023-01-01 2023-12-31 C001553 1208 NORTH DRUID HILLS, Distribution, Unattended 2023-12-31 C001553 1544 SCHERER FGD 3/4, Generation, Attended 2023-12-31 C001553 1056 MARTIN MARIETTA (Gray), Distribution, Unattended 2023-12-31 C001553 1921 WAVERLY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1899 WALKER CO. INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Mississippi, 2023-12-31 C001553 1049 MARK EVANS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 HATCH, THALMANN-DUVAL 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 352 COBB PLACE, Distribution, Unattended 2023-12-31 C001553 941 KINCHAFOONEE, Distribution, Unattended 2023-12-31 C001553 City of Troy City of Troy City of Troy FNO N/A 61 2023-01-01 2023-12-31 C001553 Riverview - Retired (E) 2023-12-31 C001553 2012 YAMAHA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1820 TYCO PLASTICS #12 PD, Distribution, Unattended 2023-12-31 C001553 1690 STONE MOUNTAIN, Distribution, Unattended 2023-12-31 C001553 Endure Energy, LLC, OS, T4 2023-01-01 2023-12-31 C001553 60 ARAGON PRIMARY, Transmission, Unattended 2023-12-31 C001553 ferc:Quarter3Member Georgia Power Company 2023-01-01 2023-12-31 C001553 SCE&G (GRANITEVILLE) 230KV , 230, 5.13, 0 2023-01-01 2023-12-31 C001553 694 GEORGIA MARBLE #2 (Whitestone), Distribution, Unattended 2023-12-31 C001553 1919 WASHINGTON, Distribution, Unattended 2023-12-31 C001553 936 KIA MOTORS, Distribution, Unattended 2023-12-31 C001553 1873 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 Property Tax - 2023, Property Tax, Georgia, 2022-12-31 C001553 Reliability ferc:ElectricUtilityMember 2023-12-31 C001553 Southern Operating CompaniesRate Schedule No. 33 , ER19-1000-000 2023-01-01 2023-12-31 C001553 21 ALADDIN FIBER ONE #8 PD, Distribution, Unattended 2023-12-31 C001553 1722 TALLULAH FALLS, Generation, Attended 2023-01-01 2023-12-31 C001553 1946 WEST GRIFFIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 10%ferc:ElectricUtilityMember 2023-12-31 C001553 Aaron P. Abramovitz 2023-01-01 2023-12-31 C001553 1934 WESLEYAN DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 40 AMERICAN GRANITE QUARRIES, Distribution, Unattended 2023-12-31 C001553 1382 POTTERY OUTLET PD (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Jobs in Progress - Cost 2023-12-31 C001553 1082 MCINTOSH CT, Generation, Attended 2023-12-31 C001553 Increases (Decreases) in Other Paid-In Capital 2023-01-01 2023-12-31 C001553 1743 TERRORA HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 127 BEASLEY TIMBER #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 468 DELTA AIRLINES #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 454 DAWSON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 WADLEY, WALLACE DAM 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 MCLB 2023-01-01 2023-12-31 C001553 Oil MCMANUS 3 & 4 2023-01-01 2023-12-31 C001553 333 CLAYTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCDONOUGH NO. 3 2023-01-01 2023-12-31 C001553 869 INTRENCHMENT CREEK SEWAGE, Distribution, Unattended 2023-12-31 C001553 1427 QUAIL HOLLOW PM, Distribution, Unattended 2023-12-31 C001553 , , , 2023-01-01 2023-12-31 C001553 1890 W. G. JOHNSON PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Southern Power (EMC 11) OS 2023-01-01 2023-12-31 C001553 GAINESVILLE 230 KV LN, 230, 45.45, 130180 2023-01-01 2023-12-31 C001553 681 GAINESVILLE WATER WORKS #2, Distribution, Unattended 2023-12-31 C001553 1392 PRATT & WHITNEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 521 DUNCAN MILL ROAD, Distribution, Unattended 2023-12-31 C001553 1713 SWEETBOTTOM, Distribution, Unattended 2023-12-31 C001553 Burke 1st Series 2008 - Variable 2023-12-31 C001553 See Attachment 261.1 2023-01-01 2023-12-31 C001553 442 DARIEN, Distribution, Unattended 2023-12-31 C001553 City of Jesup, LU, 2023-01-01 2023-12-31 C001553 1989 WINDWARD, Distribution, Unattended 2023-12-31 C001553 ferc:ElectricPollutionControlFacilitiesMember 2022-12-31 C001553 205 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 924 KATHWOOD DRIVE, Distribution, Unattended 2023-12-31 C001553 FLORIDA POWER & LIGHT COMPANY FLORIDA POWER & LIGHT COMPANY FPLNW LFP SOCOGEN 65 2023-01-01 2023-12-31 C001553 Jill Campbell 2023-01-01 2023-12-31 C001553 MCINTOSH (CC) 2023-01-01 2023-12-31 C001553 1778 TOLLESON LUMBER (Perry), Distribution, Unattended 2023-12-31 C001553 270 CANNONGATE ACRES PM, Distribution, Unattended 2023-12-31 C001553 677 GAINESVILLE #2, Distribution, Unattended 2023-12-31 C001553 987 LIKEN INDUSTRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1705 SUWANEE, Transmission, Unattended 2023-12-31 C001553 ferc:DistributionPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 710 GEORGIA PORTS AUTHORITY, Distribution, Unattended 2023-12-31 C001553 728 GOAT ROCK HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 1947 WEST MABLETON, Distribution, Unattended 2023-12-31 C001553 458 DEARING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Long-Term Service Agreement 2022-12-31 C001553 Burke 1st Series 2013 - 2.93% 2023-12-31 C001553 1032 MAGNOLIA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1579 SILGAN PLASTICS, Distribution, Unattended 2023-12-31 C001553 1582 SINCLAIR DAM HYDRO, Generation, Attended 2023-12-31 C001553 1195 NEWELL RECYCLING #1 (East Point), Distribution, Unattended 2023-12-31 C001553 472 DEMOREST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 587 EVANS CLAY, Distribution, Unattended 2023-12-31 C001553 653 FORT GORDON HOSPITAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 907 JOHNS CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 123 BAXLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 293 CEDAR VILLAGE, Distribution, Unattended 2023-12-31 C001553 1554 SCHERER UNIT 4, Generation, Attended 2023-12-31 C001553 1934 WESLEYAN DRIVE, Distribution, Unattended 2023-12-31 C001553 1530 SANDY SPRINGS, Distribution, Unattended 2023-12-31 C001553 1083 MCINTOSH TRAIL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 974 LANGBOARD (Quitman), Distribution, Unattended 2023-12-31 C001553 104 BAKERS FERRY ROAD, Distribution, Unattended 2023-12-31 C001553 Short-Term Borrowings 2022-01-01 2022-12-31 C001553 1003 LITTLE RIVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 102 BAKER PLACE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1691 STONEWALL STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 414 CRAWFORDVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 434 DACULA, Distribution, Unattended 2023-12-31 C001553 960 LAGRANGE, Distribution, Unattended 2023-12-31 C001553 879 JACK MCDONOUGH, Generation, Attended 2023-01-01 2023-12-31 C001553 743 GOSHEN (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 808 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 1359 PLAINS, Distribution, Unattended 2023-12-31 C001553 1454 REMERTON, Distribution, Unattended 2023-12-31 C001553 1633 SOUTH VILLA RICA, Distribution, Unattended 2023-12-31 C001553 Nuclear Decommissioning 2023-01-01 2023-12-31 C001553 1297 PACKAGING CORPORATION (Macon), Distribution, Unattended 2023-12-31 C001553 1100 MEDUSA PORTLAND CEMENT, Distribution, Unattended 2023-12-31 C001553 1978 WILSON, Generation, Attended 2023-12-31 C001553 218 BROAD RIVER FOREST PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Distribution Line Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Dawson Crossing-S Dahlonega 500kv T/L 2023-01-01 2023-12-31 C001553 733 GOLD MINE, Distribution, Unattended 2023-12-31 C001553 217 BRIDGEPORT BRASS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 832 HINESVILLE PRIMARY, Transmission, Unattended 2023-12-31 C001553 Plant Retirements 2022-12-31 C001553 714 GEORGIA TECH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Graphic Packaging International, OS, 2023-01-01 2023-12-31 C001553 Premium on Reacquired Debt ferc:ElectricUtilityMember 2022-12-31 C001553 Southern Electric Generating Company 2023-12-31 C001553 55 APAC (Camak), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Savannah Portside International- Old River Road Substation Site 2023-01-01 2023-12-31 C001553 Tennessee Valley Authority OS 2023-01-01 2023-12-31 C001553 Bartow 1st Series 1997 - 1.80% 2023-12-31 C001553 External Decommissioning 2022-12-31 C001553 W BRUNSWICK 230 KV LN, 230, 100.54, 479345 2023-01-01 2023-12-31 C001553 37 ALTAMAHA BOULEVARD, Distribution, Unattended 2023-12-31 C001553 596 FAIRINGTON RIDGE PM, Distribution, Unattended 2023-12-31 C001553 188 BOSTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 8 ADDLESTONE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 (5) ENVIRONMENTAL, Advanced End Use Technology 930.2 2023-01-01 2023-12-31 C001553 Southern Electric Generating Co.ferc:EquityContributionMember 2022-12-31 C001553 1284 OPHELIA SMITH PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Federal Income Taxes 2022 & Prior, Income Tax, ,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 968 LAKE SUSIE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1391 PPG INDUSTRIES, Distribution, Unattended 2023-01-01 2023-12-31 C001553 606 FIELDALE FARMS #1 (Murrayville), Distribution, Unattended 2023-12-31 C001553 1355 PINSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Transmission Line Additions & Improvements ferc:ElectricUtilityMember 2023-12-31 C001553 Burke 1st Series 1996 - Variable 2023-12-31 C001553 370 COLONIAL PIPELINE (Powder Springs), Distribution, Unattended 2023-12-31 C001553 PORTERDALE PRI 230 KV , 230, 7.4, 0 2023-01-01 2023-12-31 C001553 1063 MARVIN GRIFFIN ROAD, Distribution, Unattended 2023-12-31 C001553 1126 MILLIKEN (Alma), Distribution, Unattended 2023-01-01 2023-12-31 C001553 405 CORNELL AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 630 FLOWERY BRANCH, Distribution, Unattended 2023-12-31 C001553 1923 WAX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Walton Electric Membership Corporation, OS, 2023-01-01 2023-12-31 C001553 639 FORREST ROAD (Columbus), Distribution, Unattended 2023-12-31 C001553 1844 US 1 RECYCLING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Long-Term Service Agreement 2023-01-01 2023-12-31 C001553 1091 MCMANUS, Generation, Attended 2023-12-31 C001553 1950 WEYERHAEUSER (Colbert), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1461 REST HAVEN, Distribution, Unattended 2023-12-31 C001553 1289 OVERLAND TRAIL LAND PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 167 BLOOMINGDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 671 FURYS FERRY, Distribution, Unattended 2023-12-31 C001553 1853 VICTORY DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1306 PALM STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1442 REAL DEALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 620 FLAT ROCK ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 875 J. R. YOUNG PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1423 PUTNAM PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCLB 2023-12-31 C001553 1106 MELDRIM, Transmission, Unattended 2023-12-31 C001553 1531 SAPA EXTRUDER, Distribution, Unattended 2023-12-31 C001553 1824 U.S. CAN (Tallapoosa), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1689 STOKES LAKE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1725 TALLULAH FALLS, Generation, Attended 2023-12-31 C001553 Southern Electric Generating Co.ferc:EquityContributionMember 2023-01-01 2023-12-31 C001553 1312 PARKDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 411 COVINGTON INDUSTRIAL, Transmission, Unattended 2023-12-31 C001553 115 BARTLETTS FERRY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 598 FAYETTEVILLE, Distribution, Unattended 2023-12-31 C001553 680 GAINESVILLE WATER WORKS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1351 PILGRIMS PRIDE (Canton), Distribution, Unattended 2023-12-31 C001553 347 COBB MARIETTA WATER #2 (Johnson Ferry), Distribution, Unattended 2023-12-31 C001553 1015 LOOKOUT VALLEY, Transmission, Unattended 2023-12-31 C001553 1390 POWERS FERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Accounts (Specify, details in footnote): 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember Load Related System Improvements 2023-12-31 C001553 1487 ROBINS AFB #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Midwest Independent Trans System, OS, T4 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:MayMember 2023-01-01 2023-12-31 C001553 2023 ZEBULON ROAD, Distribution, Unattended 2023-12-31 C001553 1769 TILLY MILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 711 GEORGIA SQUARE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Monroe 1st Series 2013 - Variable 2023-01-01 2023-12-31 C001553 Miscellaneous 2023-01-01 2023-09-30 C001553 Plant Scherer - Water ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Birdsong Corporation, LU, 2023-01-01 2023-12-31 C001553 DSM Over Recovery 2023-12-31 C001553 1114 METTER PRIMARY, Distribution, Unattended 2023-12-31 C001553 746 GRABALL, Distribution, Unattended 2023-12-31 C001553 848 HUDSON WIRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1607 SOUTH ATHENS, Distribution, Unattended 2023-12-31 C001553 Duke Energy Carolinas, LLC, OS, T4 2023-01-01 2023-12-31 C001553 , 115, 12, 2023-01-01 2023-12-31 C001553 259 CADWELL PD, Distribution, Unattended 2023-12-31 C001553 1231 NORTH SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Coal SCHERER 2023-01-01 2023-12-31 C001553 Bartow 1st Series 2022 - Variable 2023-12-31 C001553 1892 W. L. BONNELL #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 415 CREEK PARK, Distribution, Unattended 2023-12-31 C001553 590 EVERGREEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTPDGSDI Real Time Pricing Day Ahead - Time of Use - General Service Demand 2023-01-01 2023-12-31 C001553 FLORIDA POWER & LIGHT COMPANY EXELON GENERATION COMPANY, LLC GTC LFP DANIEL 489 2023-01-01 2023-12-31 C001553 MERCURIA ENERGY AMERICA, LLC. MERCURIA ENERGY AMERICA, LLC. GTC LFP LINDSAY HILL 220 2023-01-01 2023-12-31 C001553 2177, NORTH HIGHLANDS 2023-12-31 C001553 1173 MOUNTAIN HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1525 SALE CITY, Distribution, Unattended 2023-12-31 C001553 1869 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 0 ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1141 MODULAR CONTAINER SYSTEMS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 644 FORT BENNING, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1147 MONK ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Deferred Credits 2023-01-01 2023-12-31 C001553 1182 MULLITE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 266 CAMP JOSEY #2 PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1708 SWAINSBORO AREA #2 PM, Distribution, Unattended 2023-12-31 C001553 460 DECATUR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Alabama, 2022-12-31 C001553 1612 SOUTH CLEVELAND, Distribution, Unattended 2023-12-31 C001553 1923 WAX, Distribution, Unattended 2023-12-31 C001553 Material Sale, Alabama Power Company 2023-01-01 2023-12-31 C001553 158 BLACKSHEAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 536 EAST EVANS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 326 CITGO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Allen Reaves 2023-01-01 2023-12-31 C001553 1117 MILL CITY SEWAGE PM, Distribution, Unattended 2023-12-31 C001553 VOGTLE 1&2 Nuclear 2023-01-01 2023-12-31 C001553 0, ROCKY MOUNTAIN 2023-01-01 2023-12-31 C001553 Plant Bowen - Air 2023-01-01 2023-12-31 C001553 1238 NORTH TIFTON, Transmission, Unattended 2023-12-31 C001553 Distribution Network Improvements - Miscellaneous ferc:ElectricUtilityMember 2023-12-31 C001553 Revenue Erosion 2022-12-31 C001553 Pooled Equipment Inventory Operating 2022-12-31 C001553 , 115, 1056.62, 159943044 2023-01-01 2023-12-31 C001553 1746 THALMANN, Transmission, Unattended 2023-12-31 C001553 463 DEKALB COUNTY SCOTT CANDLER WFP, Distribution, Unattended 2023-01-01 2023-12-31 C001553 177 BOJO, Distribution, Unattended 2023-12-31 C001553 996 LITE-N-TIE (Postell) PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1966 WILDER ROAD PM, Distribution, Unattended 2023-12-31 C001553 ferc:CaptialStockMember Southern Electric Generating Co. (1st Issuance) 2022-12-31 C001553 Deferred Revenue (a) 2023-01-01 2023-12-31 C001553 1001 LITTLE NEW YORK PM, Distribution, Unattended 2023-12-31 C001553 1150 MONROE INDUSTRIAL PD, Distribution, Unattended 2023-12-31 C001553 443 DAVIDSON MINERAL (Lithonia), Distribution, Unattended 2023-01-01 2023-12-31 C001553 446 DAVIS STREET, Transmission, Unattended 2023-12-31 C001553 1977 WILSON, Generation, Attended 2023-12-31 C001553 1257 NUTRASWEET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1019 LUCENT TECHNOLOGIES #1 (OFS FITEL), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2021A - 3.25% 2023-12-31 C001553 North Carolina EMC, OS, T4 2023-01-01 2023-12-31 C001553 611 FIFTEENTH STREET, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1493 ROBINS AFB SOLAR (IC-491), Generation, Attended 2023-01-01 2023-12-31 C001553 1817 TYBEE ISLAND, Distribution, Unattended 2023-12-31 C001553 , Electric Power Research Institute 588 2023-01-01 2023-12-31 C001553 539 EAST MAYSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous Distribution Substation Additions & Improvements ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 732 GODLEY TRACT, Distribution, Unattended 2023-12-31 C001553 449 DAWSON, Distribution, Unattended 2023-12-31 C001553 1547 SCHERER UNIT 1, Generation, Attended 2023-01-01 2023-12-31 C001553 Outdoor Lighting Projects ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1304 PACTIV #7, Distribution, Unattended 2023-01-01 2023-12-31 C001553 MCINTOSH CT 230 KV LN, 230, 0.42, 0 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember ferc:ElectricPlantInServiceMember 2022-12-31 C001553 285 CASTLEBERRY ROAD, Distribution, Unattended 2023-12-31 C001553 1843 UPS DATA CENTER (Alpharetta), Distribution, Unattended 2023-12-31 C001553 809 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 237 BUENA VISTA, Distribution, Unattended 2023-12-31 C001553 4%ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 768 GREYSTONE GOLF #2 PM, Distribution, Unattended 2023-12-31 C001553 1526 SALEM GATE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Southern Company Services, Inc.Rate Schedule No. 138, ER22-1820-001 2023-01-01 2023-12-31 C001553 277 CARNESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 70 ASAMA COLDWATER MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 441 DANIMER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 744 GOSSEN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 3 ABCD FARMS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 HATCH 2023-01-01 2023-12-31 C001553 877 J. T. RYERSON & SON #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ROCK SPRINGS 230 KV LN, 230, 15.35, 0 2023-01-01 2023-12-31 C001553 1146 MOLENA PRIMARY, Transmission, Unattended 2023-12-31 C001553 755 GRAY, Distribution, Unattended 2023-12-31 C001553 1867 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 1634 SOUTH VILLA RICA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1159 MORGAN PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 547 EASTANOLLEE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 432 CUTHBERT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1963 WHITESTONE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Dublin Solar I LLC, OS, 2023-01-01 2023-12-31 C001553 1480 RIVERSTONE, Distribution, Unattended 2023-12-31 C001553 858 INDUSTRIAL PARK DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:NonUtilityMember Other Income and Deductions 2022-12-31 C001553 Heard 1st Series 1997 - Variable 2023-12-31 C001553 1173 MOUNTAIN HILL, Distribution, Unattended 2023-12-31 C001553 193 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 1628 SOUTH NORCROSS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:PropertyTaxMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 NORCROSS 230 KV LN, 230, 12.11, 706113 2023-01-01 2023-12-31 C001553 1376 PORTERDALE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1714 SWEETBOTTOM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1987 WINDER PRIMARY, Distribution, Unattended 2023-12-31 C001553 Bartow 1st Series 2013 - 2.88% 2023-12-31 C001553 1377 PORTERDALE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1832 UNILEVER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 397 COOPER TOOLS, Distribution, Unattended 2023-12-31 C001553 1614 SOUTH COLUMBUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Distribution 2023-01-01 2023-12-31 C001553 1320 PAUL WINNIE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1695 SUMMER LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 504 DORAVILLE, Distribution, Unattended 2023-12-31 C001553 1918 WARRENTON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 751 GRANITEVILLE (Sibley), Distribution, Unattended 2023-01-01 2023-12-31 C001553 438 DALTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 134 BELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1008 LOCH LAUREL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Morgan Stanley Capital Group, Inc., OS, T4 2023-01-01 2023-12-31 C001553 1186 NACOOCHEE, Generation, Attended 2023-01-01 2023-12-31 C001553 762 GREENSBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1065 MCBEAN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 449 DAWSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 829 HIGHWAY 51 PM (Hartwell), Distribution, Unattended 2023-01-01 2023-12-31 C001553 DOE Loan 2.537% - 2044 2 2023-01-01 2023-12-31 C001553 1415 PROPEX #6 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1677 STATESBORO, Distribution, Unattended 2023-12-31 C001553 1228 NORTH RIVERSIDE, Distribution, Unattended 2023-12-31 C001553 1870 VOGTLE 1&2, Generation, Attended 2023-01-01 2023-12-31 C001553 160 BLACKWELLS, Distribution, Unattended 2023-12-31 C001553 1389 POWER PARTNERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1884 VULCAN MATERIALS (Columbus), Distribution, Unattended 2023-01-01 2023-12-31 C001553 451 DAWSON FOREST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BOWEN Coal 2023-01-01 2023-12-31 C001553 764 GREENVILLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 135 BELLEVUE, Distribution, Unattended 2023-12-31 C001553 Common Stock (No Par) 2023-01-01 2023-12-31 C001553 1165 MOULTRIE, Distribution, Unattended 2023-12-31 C001553 914 JUNCTION CITY, Distribution, Unattended 2023-12-31 C001553 1182 MULLITE #2, Distribution, Unattended 2023-12-31 C001553 System Flow Projects ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1992 WINN DIXIE PM (Powder Springs), Distribution, Unattended 2023-12-31 C001553 1029 MACON COUNTY PRISON #1 PD (South), Distribution, Unattended 2023-01-01 2023-12-31 C001553 61 ARBOR, Distribution, Unattended 2023-12-31 C001553 467 DEKALB VOCATIONAL SCHOOL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 881 JACK MCDONOUGH CC #4, Generation, Attended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Mississippi,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1563 SEALY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 659 FORTY FIFTH STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Advanced Contribution for 2023-12-31 C001553 Duke Energy OS 2023-01-01 2023-12-31 C001553 193 BOWEN, Generation, Attended 2023-12-31 C001553 , 46, 2110.27, 43151508 2023-01-01 2023-12-31 C001553 2 ABCD FARMS PM, Distribution, Unattended 2023-12-31 C001553 406 CORNELL AVENUE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1552 SCHERER UNIT 3, Generation, Attended 2023-12-31 C001553 1630 SOUTH OGLETHORPE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 286 CASTLEBERRY ROAD, Distribution, Unattended 2023-12-31 C001553 165 BLOOMFIELD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1723 TALLULAH FALLS, Generation, Attended 2023-12-31 C001553 Stewart County ferc:LandAndRightsMember 2023-01-01 2023-12-31 C001553 EAST POINT 230 KV LN, 230, 12.35, 283746 2023-01-01 2023-12-31 C001553 DOE Loan 3.488% - 2044 2023-12-31 C001553 375 COLUMBUS FOUNDRY, Distribution, Unattended 2023-12-31 C001553 408 COTTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 Bartow 1st Series 2022 - Variable 2023-01-01 2023-12-31 C001553 DUM JON 230 KV LN, 230, 34.11, 4321459 2023-01-01 2023-12-31 C001553 1890 W. G. JOHNSON PM, Distribution, Unattended 2023-12-31 C001553 1367 PLANTATION ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 808 HATCH, Generation, Attended 2023-12-31 C001553 1522 SAINT MARYS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BARNESVILLE PRI 230 KV LN, 230, 1.6, 111492 2023-01-01 2023-12-31 C001553 515 DSM EVERGREEN, Distribution, Unattended 2023-12-31 C001553 1408 PROPEX #2 (Hazlehurst), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Intangible ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1704 SUTTONS CROSSROAD, Distribution, Unattended 2023-12-31 C001553 1018 LOUISVILLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1023 LYLE CIRCLE PD, Distribution, Unattended 2023-12-31 C001553 1011 LOCKHEED MARTIN #2, Distribution, Unattended 2023-12-31 C001553 1556 SCHERER UNIT 4, Generation, Attended 2023-12-31 C001553 1730 TARA, Distribution, Unattended 2023-12-31 C001553 Municipal Electric Authority Of Georgia, LU, 2023-01-01 2023-12-31 C001553 Estimated Loss on Plant Vogtle Units 3 and 4 2023-01-01 2023-12-31 C001553 366 COLONIAL PIPELINE (Bremen), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1233 NORTH STATESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 757 GREAT SOUTHWEST AMUSEMENT PARK, Distribution, Unattended 2023-12-31 C001553 357 COCHRAN PRIMARY, Distribution, Unattended 2023-12-31 C001553 1458 RENESSENZ, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Joint Owner Other Deferred Billings 2022-12-31 C001553 647 FORT BENNING #2, Transmission, Unattended 2023-12-31 C001553 685 GARNETT RIDGE PM, Distribution, Unattended 2023-12-31 C001553 ferc:GasOtherFacilitiesMember Other (provide details in footnote): 2023-01-01 2023-12-31 C001553 1992 WINN DIXIE PM (Powder Springs), Distribution, Unattended 2023-01-01 2023-12-31 C001553 212 BRADLEY INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1815 TY TY PD, Distribution, Unattended 2023-12-31 C001553 ferc:PayrollTaxMember 2022-12-31 C001553 324 CHOKEE PLANTATION #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 991 LINDALE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 556 EATONTON RADIO STATION PM, Distribution, Unattended 2023-12-31 C001553 Plant Yates - Water ferc:ElectricUtilityMember 2023-12-31 C001553 297 CENTRAL STATE HOSPITAL, Distribution, Unattended 2023-12-31 C001553 559 ELANCO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1929 WAYNESBORO PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 499 DODGE EASTMAN INDUSTRIAL PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 225 BROOKHAVEN BOULEVARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1481 RIVERVIEW HYDRO, Generation, Attended 2023-01-01 2023-12-31 C001553 541 EAST POINT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1042 MALL OF GEORGIA, Distribution, Unattended 2023-12-31 C001553 31 ALDORA MILLS #3, Distribution, Unattended 2023-12-31 C001553 821 HERCULES (Savannah), Distribution, Unattended 2023-01-01 2023-12-31 C001553 FUTA, Payroll Tax, 0, 2023-12-31 C001553 SMYRNA 230 KV LN, 230, 7.15, 805018 2023-01-01 2023-12-31 C001553 1058 MARTIN MARIETTA (Junction City), Distribution, Unattended 2023-12-31 C001553 1983 WILSON, Generation, Attended 2023-12-31 C001553 Tennessee Valley Authority, OS, T4 2023-01-01 2023-12-31 C001553 736 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-12-31 C001553 Plant Hatch - Electrical 2023-01-01 2023-12-31 C001553 W BRUNSWICK #1 230 KV LN, 230, 39.22, 131794 2023-01-01 2023-12-31 C001553 846 HUB JUNCTION PM, Distribution, Unattended 2023-12-31 C001553 1787 TRANSCO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1477 RIVERDALE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 508 DOUBLE BRIDGES ROAD PM, Distribution, Unattended 2023-12-31 C001553 675 GAINER COTTON GIN, Distribution, Unattended 2023-12-31 C001553 ferc:SulfurDioxideMember 2022-12-31 C001553 Bethabara-E. Walton 230kv T/L Site 2023-01-01 2023-12-31 C001553 824 HERTY LABS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 997 LITHONIA, Distribution, Unattended 2023-12-31 C001553 353 2023-01-01 2023-12-31 C001553 1020 LUCENT TECHNOLOGIES #2 (OFS FITEL), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other 2023-01-01 2023-12-31 C001553 FLAT-GS Flat Bill - General Service 2023-01-01 2023-12-31 C001553 658 FORTY FIFTH STREET, Distribution, Unattended 2023-12-31 C001553 1293 OWL HEAD #2, Distribution, Unattended 2023-12-31 C001553 Distribution Total 2023-01-01 2023-12-31 C001553 Series 2023C - Variable 2023-12-31 C001553 894 JAMESTOWN, Distribution, Unattended 2023-12-31 C001553 1547 SCHERER UNIT 1, Generation, Attended 2023-12-31 C001553 Series 2020B - 3.70% 2023-12-31 C001553 153 BIG POPLAR, Distribution, Unattended 2023-12-31 C001553 1101 MEDUSA PORTLAND CEMENT #2, Distribution, Unattended 2023-12-31 C001553 1027 MABLETON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2177, GOAT ROCK 2023-12-31 C001553 393 CONYERS, Transmission, Unattended 2023-12-31 C001553 HSH Pembroke LLC, LU, 2023-01-01 2023-12-31 C001553 1765 THOMSON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 643 FORSTMANN (Louisville), Distribution, Unattended 2023-12-31 C001553 635 FOREST PARK, Distribution, Unattended 2023-12-31 C001553 933 KETTLE CREEK, Distribution, Unattended 2023-12-31 C001553 813 HATCH SITE #2, Distribution, Unattended 2023-12-31 C001553 1839 UNIVERSITY OF GEORGIA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Non Current Fuel Cost Recovery 2023-12-31 C001553 The Energy Authority, OS, T4 2023-01-01 2023-12-31 C001553 (3) DISTRIBUTION, Power Delivery Distribution Research 2023-01-01 2023-12-31 C001553 1139 MITCHELL 115, Transmission, Unattended 2023-12-31 C001553 Burke 4th Series 1994 - 2.25% 2023-01-01 2023-12-31 C001553 Balancing Operating Reserve 2023-01-01 2023-09-30 C001553 FICA, Payroll Tax, 0,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 189 BOULEVARD (Atlanta), Transmission, Unattended 2023-01-01 2023-12-31 C001553 171 BOAT ROCK ROAD, Distribution, Unattended 2023-12-31 C001553 1814 TWIN PINES, Distribution, Unattended 2023-12-31 C001553 ferc:DirectPayrollDistributionMember Jobbing Work in Progress 2023-01-01 2023-12-31 C001553 TOUEO-C Time-of-Use - Energy Only 2023-01-01 2023-12-31 C001553 726 GLYNDALE ROAD, Distribution, Unattended 2023-12-31 C001553 1040 MAIN STREET PD (RETIRED), Distribution, Unattended 2023-01-01 2023-12-31 C001553 165 BLOOMFIELD, Distribution, Unattended 2023-12-31 C001553 SEMINOLE ELECTRIC COOPERATIVE INCORPORATED SEMINOLE ELECTRIC COOPERATIVE INCORPORATED FPL LFP DANIEL 100 2023-01-01 2023-12-31 C001553 WINDER 230KV LN, , , 0 2023-01-01 2023-12-31 C001553 1206 NORTH COLUMBUS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 918 KAMIN (Wrens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Debit or Cr. Items (Describe, details in footnote): 2023-01-01 2023-12-31 C001553 Heard 1st Series 1996 - Variable 2023-01-01 2023-12-31 C001553 Utility Services Contracts (d) 2022-12-31 C001553 1621 SOUTH MACON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1166 MOULTRIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1937 WEST AUGUSTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 319 CHINA HILL ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1917 WARRENTON PRIMARY, Transmission, Unattended 2023-12-31 C001553 314 CHICOPEE MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 1261 OAK STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 WILSON 2023-12-31 C001553 119 BASSETT FURNITURE, Distribution, Unattended 2023-12-31 C001553 1332 PEEPLES VALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 312 CHICKAMAUGA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1310 PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1853 VICTORY DRIVE, Distribution, Unattended 2023-12-31 C001553 ALTERNATIVE RATE PLAN - 2023-01-01 2023-12-31 C001553 44 AMHERST, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1620 SOUTH GEORGIA METHODIST NURSING HOME, Distribution, Unattended 2023-12-31 C001553 1104 MELDRIM, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1997 WOODBURY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1281 OLIVER DAM HYDRO, Generation, Attended 2023-12-31 C001553 1215 NORTH HIGHLANDS, Generation, Attended 2023-12-31 C001553 INTEGRATED RESOURCE PLAN - DOCKET NOS. 42641, 42310, 45084, 44160, and 55378 2023-01-01 2023-12-31 C001553 1784 TOYO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 689 GEORGETOWN (Savannah), Distribution, Unattended 2023-12-31 C001553 438 DALTON, Distribution, Unattended 2023-12-31 C001553 196 BOWEN, Generation, Attended 2023-01-01 2023-12-31 C001553 915 JUNCTION CITY, Distribution, Unattended 2023-12-31 C001553 247 BURGESS PIGMENT, Distribution, Unattended 2023-12-31 C001553 1767 THREE RIVERS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1995 WINTERVILLE, Distribution, Unattended 2023-12-31 C001553 1124 MILLHAVEN ANNEX, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Bartow 1st Series 1997 - 1.80% 2023-01-01 2023-12-31 C001553 1142 MOHAWK INDUSTRIES (East Dublin), Distribution, Unattended 2023-01-01 2023-12-31 C001553 328 CLARKESVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 792 HARGROVE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1439 RAYONIER (Eatonton), Distribution, Unattended 2023-12-31 C001553 152 BIG POPLAR, Distribution, Unattended 2023-01-01 2023-12-31 C001553 20231121-5123, 45251, ER24-457-000 2023-01-01 2023-12-31 C001553 1812 TWIN LAKES, Transmission, Unattended 2023-12-31 C001553 Monroe 2nd Series 2006 - Variable 2023-01-01 2023-12-31 C001553 873 J. M. HUBER (Reids), Distribution, Unattended 2023-12-31 C001553 ELLIJAY 230 KV LN, 230, 5, 0 2023-01-01 2023-12-31 C001553 1640 SOUTHERN BELL, Distribution, Unattended 2023-12-31 C001553 863 INTERNATIONAL PLAYTEX, Distribution, Unattended 2023-01-01 2023-12-31 C001553 128 BEAULIEU AMERICA (Royston), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1673 STANTON SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 228 BROWN BROTHERS #2, Distribution, Unattended 2023-12-31 C001553 Distribution New Business ferc:ElectricUtilityMember 2023-12-31 C001553 57 AQUILLA, Distribution, Unattended 2023-12-31 C001553 440 DAMES FERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RUSSELL DAM 230 KV LN, 230, 2.88, 2648 2023-01-01 2023-12-31 C001553 610 FIFE, Distribution, Unattended 2023-12-31 C001553 601 FAYETTEVILLE ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 353 COBB PLACE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Series 2007 D - 6.375% 2023-01-01 2023-12-31 C001553 514 DSM CHEMICALS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 384 CONCORD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 989 LIMESTONE CREEK PM, Distribution, Unattended 2023-12-31 C001553 1662 SPARTA #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Deferred Income Taxes 2022-12-31 C001553 1431 RADIUM SPRINGS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Hecate Energy Old Midville Rd, LLC, LU, 2023-01-01 2023-12-31 C001553 1213 NORTH GRIFFIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 483 DILLARD PRIMARY, Distribution, Unattended 2023-12-31 C001553 Progress Payments 2023-12-31 C001553 734 GOLDEN PEANUT (Dawson), Distribution, Unattended 2023-12-31 C001553 ferc:ElectricPollutionControlFacilitiesMember 2023-01-01 2023-12-31 C001553 434 DACULA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 738 GOODYEAR TIRE (Social Circle), Distribution, Unattended 2023-12-31 C001553 10% 2023-01-01 2023-12-31 C001553 1980 WILSON, Generation, Attended 2023-12-31 C001553 392 CONYERS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Miscellaneous ferc:ElectricUtilityMember 2023-12-31 C001553 957 LAFARGE AGGREGATES #1 Douglasville, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Roderick W. Anderson 2023-01-01 2023-12-31 C001553 512 DRURY PM, Distribution, Unattended 2023-12-31 C001553 45 ANCHOR GLASS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1807 TUCKER, Distribution, Unattended 2023-12-31 C001553 1349 PILGRIMS PRIDE #2 (Athens), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Yates - Water 2023-01-01 2023-12-31 C001553 Federal Income Taxes 2023, Income Tax, , 2023-01-01 2023-12-31 C001553 ferc:TransmissionSubstationMember 2023-12-31 C001553 ferc:DirectPayrollDistributionMember General Shops Expenses 2023-01-01 2023-12-31 C001553 735 GOODSON ROAD #2 PM, Distribution, Unattended 2023-12-31 C001553 1244 NORTHPARK, Distribution, Unattended 2023-12-31 C001553 DOE Loan 2.537% - 2044 2023-12-31 C001553 WANSLEY , OHARA 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 Macquarie Energy, LLC, OS, T4 2023-01-01 2023-12-31 C001553 294 CEDARTOWN, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1740 TENNILLE CITY, Distribution, Unattended 2023-12-31 C001553 1795 TRI COUNTY FARMS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 McGrau Ford BESS Site ferc:LandAndRightsMember 2023-12-31 C001553 1928 WAYNESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 511 DRURY PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Wilson CT - Miscellaneous Additions ferc:ElectricUtilityMember 2023-12-31 C001553 Net Worth, Other License And Fees Tax, Georgia, 2022-12-31 C001553 971 LAKELAND, Distribution, Unattended 2023-12-31 C001553 1656 SOUTHWIRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 TOU-RD Time-of-Use - Residential Demand 2023-01-01 2023-12-31 C001553 803 HATCH, Generation, Attended 2023-12-31 C001553 807 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 1880 VOGTLE 3&4 500KV, Generation, Attended 2023-12-31 C001553 223 BRONWOOD, Distribution, Unattended 2023-12-31 C001553 1453 REIDSVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 852 HUSQVARNA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 595 FAIR ROAD, Distribution, Unattended 2023-12-31 C001553 MARTA, LU, 2023-01-01 2023-12-31 C001553 1784 TOYO, Distribution, Unattended 2023-12-31 C001553 1838 UNIVERSITY CENTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 FLA ST LN 230 KV LN, 230, 64.64, 298930 2023-01-01 2023-12-31 C001553 Non Current Fuel Cost Recovery 2022-12-31 C001553 97 AUTREY FURNITURE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1428 QUAIL RIDGE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1888 VULCAN MATERIALS (Madras), Distribution, Unattended 2023-12-31 C001553 KINGSLAND 230 KV LN, 230, 35.96, 1031771 2023-01-01 2023-12-31 C001553 47 ANDERSONVILLE PD, Distribution, Unattended 2023-12-31 C001553 1839 UNIVERSITY OF GEORGIA, Distribution, Unattended 2023-12-31 C001553 812 HATCH SITE #1, Distribution, Unattended 2023-12-31 C001553 50 ANTHONY PM, Distribution, Unattended 2023-12-31 C001553 Generating Plant Outage Costs 2023-12-31 C001553 1995 WINTERVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 215 BRIAR VISTA, Distribution, Unattended 2023-12-31 C001553 1378 PORTERDALE PRIMARY, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Alabama, 2023-12-31 C001553 1785 TRANQUILLA HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 64 ARLINGTON, Distribution, Unattended 2023-12-31 C001553 1396 PREFERRED COMPOUNDING #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 77 ATHENS OPERATING PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1665 SPRING STREET, Distribution, Unattended 2023-12-31 C001553 359 2023-01-01 2023-12-31 C001553 International Paper Flint River, LU, 2023-01-01 2023-12-31 C001553 264 CALHOUN ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 672 FURYS FERRY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 476 DERING CIRCLE 230, Distribution, Unattended 2023-01-01 2023-12-31 C001553 890 JACK MCDONOUGH CC #6, Generation, Attended 2023-12-31 C001553 ferc:ElectricUtilityMember FICA-COVID 19 State, Payroll Tax, 0, 2023-01-01 2023-12-31 C001553 197 BOWEN, Generation, Attended 2023-12-31 C001553 955 KRAFT 115, Transmission, Attended 2023-01-01 2023-12-31 C001553 1436 RANDALL, Distribution, Unattended 2023-12-31 C001553 Burke 5th Series 1994 - 2.15% 2023-12-31 C001553 RTHFPAI RTP Hour Ahead - Fixed Pricing Alternative 2023-01-01 2023-12-31 C001553 1629 SOUTH OGLETHORPE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1919 WASHINGTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Kimberly S. Greene, Chairman, President and CEO 2023-01-01 2023-12-31 C001553 Monroe 1st Series 1997 - Variable 2023-12-31 C001553 718 GERDAU, Distribution, Unattended 2023-12-31 C001553 1196 NEWELL RECYCLING (Norcross), Transmission, Unattended 2023-01-01 2023-12-31 C001553 1753 THIELE KAOLIN (Sandersville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 756 GREAT SOUTHWEST AMUSEMENT PARK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1095 MCPHERSON MANUFACTURING, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1904 WALTHOURVILLE, Distribution, Unattended 2023-12-31 C001553 519 DUM JON, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1545 SCHERER RIVER PUMPING, Distribution, Attended 2023-12-31 C001553 1871 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 303 CHARLES WHITLOCK PM, Distribution, Unattended 2023-12-31 C001553 ferc:SulfurDioxideMember 2023-01-01 2023-12-31 C001553 471 DELTA AIRLINES #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1272 OLD ALABAMA ROAD, Distribution, Unattended 2023-12-31 C001553 ferc:IntangiblePlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1852 VICTORY DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1567 SEWELL ROAD PM, Distribution, Unattended 2023-12-31 C001553 1597 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Tennessee, 2023-01-01 2023-12-31 C001553 ferc:OtherTaxesAndFeesMember 2022-12-31 C001553 NORTHWEST #2 230 KV LN, 230, , 23367 2023-01-01 2023-12-31 C001553 994 LINWOOD WRF, Distribution, Unattended 2023-12-31 C001553 1386 POWDER SPRINGS, Distribution, Unattended 2023-12-31 C001553 1054 MARTIN HEIGHTS PM, Distribution, Unattended 2023-12-31 C001553 1164 MOULTRIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 NORCROSS, OCONEE LN 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 Plant Yates - Water ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 281 CARWOOD MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 665 FRANKLIN ALUMINUM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 VOGTLE 3 2023-12-31 C001553 372 COLOR IMAGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Outage ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember ferc:ElectricPlantInServiceMember 2023-12-31 C001553 1160 MORGANVILLE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 161 BLAKELY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 FORD LOOP, 230, 1.97, 37744 2023-01-01 2023-12-31 C001553 Series 2010C - 4.75% 2023-01-01 2023-12-31 C001553 ferc:OtherUtilityMember Other (Specify) 2023-12-31 C001553 PLT SCHERER, O'HARA 500KV LN, , 2023-01-01 2023-12-31 C001553 488 DIXIE PIPELINE (Appling), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1604 SOLVAY ADVANCED POLYMERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1646 SOUTHERN MILLS (Zebulon), Distribution, Unattended 2023-01-01 2023-12-31 C001553 YATES #6 & #7 230 KV LN, 230, 1.4, 0 2023-01-01 2023-12-31 C001553 Deferred Revenue (a) 2022-12-31 C001553 Plant Hatch - Miscellaneous Additions 2023-01-01 2023-12-31 C001553 795 HARRISON, Distribution, Unattended 2023-12-31 C001553 805 HATCH, Generation, Attended 2023-01-01 2023-12-31 C001553 Louisville Gas & Electric, OS, 0 2023-01-01 2023-12-31 C001553 1126 MILLIKEN (Alma), Distribution, Unattended 2023-12-31 C001553 2023-01-01 2023-03-31 C001553 ROCK SPRINGS 230 KV LN, 230, 83.39, 699833 2023-01-01 2023-12-31 C001553 VOGTLE BUS #1 , VOGTLE 3&4 BUS #3, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 1773 TIOGA, Transmission, Unattended 2023-01-01 2023-12-31 C001553 1354 PINE MOUNTAIN, Distribution, Unattended 2023-12-31 C001553 139 BEN HILL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1982 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 826 HIGHTOWER ROAD PM, Distribution, Unattended 2023-12-31 C001553 816 HAZLEHURST PRIMARY, Transmission, Unattended 2023-12-31 C001553 Georgia Power Company ferc:JulyMember 2023-01-01 2023-12-31 C001553 1431 RADIUM SPRINGS, Distribution, Unattended 2023-12-31 C001553 280 CARROLLTON #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 N TIFTON 230 KV LN, 230, 35.53, 107179 2023-01-01 2023-12-31 C001553 807 HATCH, Generation, Attended 2023-12-31 C001553 1783 TOWNSEND, Distribution, Unattended 2023-01-01 2023-12-31 C001553 929 KENNESAW, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1818 TYCO PLASTICS #1, Distribution, Unattended 2023-01-01 2023-12-31 C001553 549 EASTMAN, Distribution, Unattended 2023-12-31 C001553 AUSTIN DRIVE, SCOTTDALE 230 KV LN, Steel Pole, 1351 ACSR 2023-01-01 2023-12-31 C001553 1689 STOKES LAKE PD, Distribution, Unattended 2023-12-31 C001553 1848 VARNELL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Georgia Power Company ferc:MarchMember 2023-01-01 2023-12-31 C001553 5 ACWORTH, Distribution, Unattended 2023-12-31 C001553 238 BUENA VISTA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1133 MILLIKEN (Pine Mountain), Distribution, Unattended 2023-12-31 C001553 381 COMMERCE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1881 VOGTLE 3&4 500KV, Generation, Attended 2023-01-01 2023-12-31 C001553 373 2023-01-01 2023-12-31 C001553 , 69, 2.79, 127202 2023-01-01 2023-12-31 C001553 650 FORT GILLEM, Distribution, Unattended 2023-12-31 C001553 Other (provide details in footnote): 2022-01-01 2022-12-31 C001553 Property Tax - 2022, Property Tax, Tennessee, 2022-12-31 C001553 1088 MCMANUS, Generation, Attended 2023-01-01 2023-12-31 C001553 972 LAKEWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Savannah Portside International- Old River Road Substation Site ferc:LandAndRightsMember 2023-01-01 2023-12-31 C001553 Oglethorpe Power Corporation, OS, T4 2023-01-01 2023-12-31 C001553 1114 METTER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1678 STATESBORO AREA #8 PM, Distribution, Unattended 2023-12-31 C001553 1184 MYSTERY VALLEY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1050 MARK GLASS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 79 ATLANTA FULTON COUNTY WATER TREATMENT, Distribution, Unattended 2023-01-01 2023-12-31 C001553 994 LINWOOD WRF, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1092 MCMANUS, Generation, Attended 2023-12-31 C001553 530 EAST BAINBRIDGE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1694 STUBBS ROAD PM, Distribution, Unattended 2023-12-31 C001553 363 COLONELS ISLAND, Distribution, Unattended 2023-12-31 C001553 Louisville Gas & Electric, OS, 2023-01-01 2023-12-31 C001553 INTEGRATED RESOURCE PLAN - DOCKET NOS. 42641, 42310, 45084, 44160, and 55378 2023-12-31 C001553 863 INTERNATIONAL PLAYTEX, Distribution, Unattended 2023-12-31 C001553 847 HUDSON WIRE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1867 VOGTLE 1&2, Generation, Attended 2023-12-31 C001553 25 ALADDIN MILLS #3, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1821 TYCO PLASTICS #8, Distribution, Unattended 2023-12-31 C001553 Deferred Income Taxes 2023-01-01 2023-12-31 C001553 246 BULL MOOSE TUBE, Distribution, Unattended 2023-12-31 C001553 696 GEORGIA MARBLE #5 (Marble Hill), Distribution, Unattended 2023-12-31 C001553 Effingham County Power, LLC - PPA, OS, 2023-01-01 2023-12-31 C001553 455 DEAL BRANCH, Transmission, Unattended 2023-12-31 C001553 1718 TALLAPOOSA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 506 DOSTER ROAD PM, Distribution, Unattended 2023-12-31 C001553 Gas YATES 2023-01-01 2023-12-31 C001553 ferc:SulfurDioxideMember ferc:CurrentYearMember 2023-01-01 2023-12-31 C001553 1484 ROBERTS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1011 LOCKHEED MARTIN #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 594 FAIR ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1616 SOUTH EFFINGHAM, Distribution, Unattended 2023-12-31 C001553 510 DOUBLEGATE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 814 HAWTHORNE, Distribution, Unattended 2023-12-31 C001553 BOWEN, NORCROSS 500 KV LN, Steel Towers, 1113 ACSR 2023-01-01 2023-12-31 C001553 VOGTLE 3&4 230KV RAT B LINE, 230, 0.7, 0 2023-01-01 2023-12-31 C001553 693 GEORGIA IRON WORKS, Distribution, Unattended 2023-12-31 C001553 843 HORSELEG CREEK, Distribution, Unattended 2023-12-31 C001553 1562 SEA ISLAND, Distribution, Unattended 2023-12-31 C001553 926 KEITH WHITE PD, Distribution, Unattended 2023-12-31 C001553 Plant Vogtle 1&2 - Controls 2023-01-01 2023-12-31 C001553 ferc:ElectricUtilityMember ferc:PayrollTaxMember 2023-01-01 2023-12-31 C001553 Other *ferc:ElectricUtilityMember 2022-12-31 C001553 1842 UNIVETER CROSSING, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Alabama, 2023-01-01 2023-12-31 C001553 1574 SHENANDOAH SEWAGE PM, Distribution, Unattended 2023-12-31 C001553 1506 ROPERS CORNER, Distribution, Unattended 2023-12-31 C001553 1699 SUMNER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1157 MORGAN FALLS, Distribution, Unattended 2023-12-31 C001553 1259 OAK GROVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1628 SOUTH NORCROSS, Distribution, Unattended 2023-12-31 C001553 305 CHATSWORTH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 705 GEORGIA PACIFIC (Vienna), Distribution, Unattended 2023-12-31 C001553 Property Tax - 2022, Property Tax, Alabama, 2022-12-31 C001553 Business License, Other License And Fees Tax, Mississippi, 2023-01-01 2023-12-31 C001553 1648 SOUTHERN NATURAL GAS (Ellerslie), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Additional Pension Deduction 2023-01-01 2023-12-31 C001553 875 J. R. YOUNG PM, Distribution, Unattended 2023-12-31 C001553 507 DOSTER ROAD #2 PM, Distribution, Unattended 2023-12-31 C001553 42 AMERICUS, Transmission, Unattended 2023-01-01 2023-12-31 C001553 Southeastern Power Administration, OS, T4 2023-01-01 2023-12-31 C001553 251 BURTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 252 BURTON HYDRO, Generation, Attended 2023-12-31 C001553 988 LILBURN, Distribution, Unattended 2023-12-31 C001553 1576 SHILOH, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1927 WAYNE FARMS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1263 OAKFIELD PM, Distribution, Unattended 2023-12-31 C001553 1860 VINEVILLE, Distribution, Unattended 2023-12-31 C001553 413 CRAWFORD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 699 GEORGIA MARBLE (Tate), Distribution, Unattended 2023-12-31 C001553 Distribution Services (e) 2023-12-31 C001553 956 L. L. BARNES PM, Distribution, Unattended 2023-12-31 C001553 1459 RENESSENZ, Distribution, Unattended 2023-01-01 2023-12-31 C001553 149 BIG A, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Plant Scherer - Outage Projects ferc:ElectricUtilityMember 2023-12-31 C001553 1236 NORTH THOMSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 2nd Series 2008 - 2.93% 2023-12-31 C001553 1413 PROPEX #5 (Hazlehurst), Distribution, Unattended 2023-12-31 C001553 1771 TIMBERMEN (Camak), Distribution, Unattended 2023-12-31 C001553 479 DEXTER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 317 CHILDRESS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 990 LINDALE #2, Distribution, Unattended 2023-12-31 C001553 KINGS BAY #1 230 KV LN, 230, 7.96, 535649 2023-01-01 2023-12-31 C001553 Sales Commissions (d) 2022-12-31 C001553 1528 SANDERSVILLE CLAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Credit Line Fees (b) 2022-12-31 C001553 1696 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-12-31 C001553 1752 THIELE KAOLIN (Mine), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Augusta Canal Authority, LU, 2023-01-01 2023-12-31 C001553 2023-01-01 2023-12-31 C001553 406 CORNELL AVENUE, Distribution, Unattended 2023-12-31 C001553 OGS-C Optional General Service 2023-01-01 2023-12-31 C001553 494 DIXIE PIPELINE (Shiloh), Distribution, Unattended 2023-01-01 2023-12-31 C001553 Other Basis Differences - 109 2023-01-01 2023-12-31 C001553 1122 MILLEN AREA #3 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Burke 1st Series 2012 - 2.88% 2023-01-01 2023-12-31 C001553 1316 PASCOE STEEL, Distribution, Unattended 2023-12-31 C001553 1990 WINDY HILL, Distribution, Unattended 2023-12-31 C001553 838 HOLLY DRIVE INDUSTRIAL, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Bartow 1st Series 2009 - 2.75% 2023-12-31 C001553 953 KIRKWOOD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Joint Owner Other Deferred Billings 2023-01-01 2023-12-31 C001553 213 BRADLEY INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 188 BOSTON, Distribution, Unattended 2023-12-31 C001553 Solar Self Build Projects ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1897 WABASH, Distribution, Unattended 2023-12-31 C001553 1667 SPRING STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 897 JEKYLL ISLAND, Distribution, Unattended 2023-12-31 C001553 337 CLOUDLAND CANYON, Distribution, Unattended 2023-12-31 C001553 868 INTERSTATE PAPER, Distribution, Unattended 2023-12-31 C001553 Chattahoochee Hydro Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 950 KINGSTON, Distribution, Unattended 2023-12-31 C001553 1715 SWEETWATER PAPER BOARD, Distribution, Unattended 2023-12-31 C001553 TOU-REO Time-of-Use - Residential Energy Only 2023-01-01 2023-12-31 C001553 85 ATLANTIC DRIVE, Distribution, Unattended 2023-12-31 C001553 883 JACK MCDONOUGH CC #4, Generation, Attended 2023-01-01 2023-12-31 C001553 1473 RIVER PARK, Distribution, Unattended 2023-12-31 C001553 450 DAWSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 481 DIAMOND HILL AREA PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1196 NEWELL RECYCLING (Norcross), Transmission, Unattended 2023-12-31 C001553 1951, SINCLAIR DAM 2023-01-01 2023-12-31 C001553 162 BLANCHARD INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C001553 2237, MORGAN FALLS 2023-01-01 2023-12-31 C001553 Endure Energy, LLC, OS, 2023-01-01 2023-12-31 C001553 945 KING SPRINGS ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 46 ANCHOR GLASS, Distribution, Unattended 2023-12-31 C001553 1697 SUMMERVILLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 988 LILBURN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1028 MACON COUNTY PRISON #1 PD (South), Distribution, Unattended 2023-12-31 C001553 S BAINBRIDGE, FLA ST LN 230 KV LN, Wood H-Frame, 1033 ACSR 2023-01-01 2023-12-31 C001553 835 HIRAM SUDIE PM Retired, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1652 SOUTHERN STATES CO-OP, Distribution, Unattended 2023-01-01 2023-12-31 C001553 834 HIRAM, Distribution, Unattended 2023-12-31 C001553 1552 SCHERER UNIT 3, Generation, Attended 2023-01-01 2023-12-31 C001553 1978 WILSON, Generation, Attended 2023-01-01 2023-12-31 C001553 36 ALPHARETTA, Distribution, Unattended 2023-12-31 C001553 532 EAST CUTHBERT, Distribution, Unattended 2023-12-31 C001553 979 LEARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1561 SCOVILLE MANUFACTURING, Distribution, Unattended 2023-12-31 C001553 655 FORT MCPHERSON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Charles K. Tarbutton 2023-01-01 2023-12-31 C001553 Accounts Receivable ferc:AllocationOfPayrollChargedForClearingAccountsMember 2023-01-01 2023-12-31 C001553 1783 TOWNSEND, Distribution, Unattended 2023-12-31 C001553 1693 STOWE WOODWARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1110 METAL PRODUCTS #1, Distribution, Unattended 2023-12-31 C001553 Property Tax - 2021 & Prior, Property Tax, Tennessee,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1034 MAGNOLIA BLUFF, Distribution, Unattended 2023-12-31 C001553 Cash Surrender Value Insurance (a) 2023-12-31 C001553 ferc:LandAndRightsMember Piedmont Substation Site 2023-12-31 C001553 1594 SNAPFINGER ROAD, Distribution, Unattended 2023-12-31 C001553 290 CEDAR HILL, Distribution, Unattended 2023-12-31 C001553 External Decommissioning 2023-12-31 C001553 678 GAINESVILLE #2, Distribution, Unattended 2023-12-31 C001553 52 ANTIOCH ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTPDAPSI Real Time Pricing Day Ahead - Agricultural Process Service 2023-01-01 2023-12-31 C001553 33 ALKEN-ZEIGLER, Distribution, Unattended 2023-12-31 C001553 ferc:LandAndRightsMember New Hampstead Substation 2023-12-31 C001553 Material Sale, Alabama Power Company 2023-01-01 2023-12-31 C001553 Outage ferc:ElectricUtilityMember 2023-12-31 C001553 767 GREYSTONE PM, Distribution, Unattended 2023-12-31 C001553 918 KAMIN (Wrens), Distribution, Unattended 2023-12-31 C001553 1987 WINDER PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ROBINS AIR FORCE - DOCKET 2023-12-31 C001553 1288 ORCHARD HILL, Distribution, Unattended 2023-12-31 C001553 983 LEWIS DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1144 MOHAWK INDUSTRIES (Summerville), Distribution, Unattended 2023-12-31 C001553 386 CONCORD GROVE, Distribution, Unattended 2023-12-31 C001553 640 FORREST ROAD (Columbus), Distribution, Unattended 2023-12-31 C001553 142 BERKELEY LAKE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1358 PITTS CHAPEL ROAD PM, Distribution, Unattended 2023-12-31 C001553 1396 PREFERRED COMPOUNDING #2 PM, Distribution, Unattended 2023-12-31 C001553 1555 SCHERER UNIT 4, Generation, Attended 2023-12-31 C001553 73 ASHFORD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1228 NORTH RIVERSIDE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 813 HATCH SITE #2, Distribution, Unattended 2023-01-01 2023-12-31 C001553 , Electric Power Research Institute 549 2023-01-01 2023-12-31 C001553 14 AIRLINE, Transmission, Unattended 2023-12-31 C001553 2022-01-01 2022-12-31 C001553 1600 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 E. WATKINSVILLE 230 KV LN, 230, 62.29, 2349621 2023-01-01 2023-12-31 C001553 2 ABCD FARMS PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1659 SPALDING, Distribution, Unattended 2023-12-31 C001553 1941 WEST DALLAS, Distribution, Unattended 2023-12-31 C001553 1757 THOMASTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1711 SWAINSBORO PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Enterprise Solutions System Upgrades ferc:ElectricUtilityMember 2023-12-31 C001553 1382 POTTERY OUTLET PD (RETIRED), Distribution, Unattended 2023-12-31 C001553 Tax Reserve 2023-01-01 2023-12-31 C001553 Premium on Reacquired Debt ferc:ElectricUtilityMember 2023-12-31 C001553 186 BONE PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Substation Site 2023-01-01 2023-12-31 C001553 1393 PRAYON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 410 COUNTY FARM ROAD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 129 BEAVER DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Piedmont Forrest Corporation ferc:CaptialStockMember 2022-12-31 C001553 1638 SOUTHEASTERN ASSEMBLY, Distribution, Unattended 2023-12-31 C001553 1399 PRESTON, Distribution, Unattended 2023-12-31 C001553 537 EAST LUMPKIN, Distribution, Unattended 2023-12-31 C001553 ROYAL ATL 230KV, , , 1349231 2023-01-01 2023-12-31 C001553 1519 SAGE AUTOMOTIVE INTERIORS, Distribution, Unattended 2023-12-31 C001553 20211101-5254, 44866, ER10-203-000 2023-01-01 2023-12-31 C001553 Burke 3rd Series 2012 - Variable 2023-01-01 2023-12-31 C001553 255 BUTLER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 YATES 2023-01-01 2023-12-31 C001553 663 FRANKLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1836 UNION POINT PRIMARY, Transmission, Unattended 2023-12-31 C001553 Miscellaneous General Expenses 2023-01-01 2023-12-31 C001553 979 LEARY, Distribution, Unattended 2023-12-31 C001553 908 JOHNS CREEK, Distribution, Unattended 2023-12-31 C001553 Series 2016A - 3.25% 2023-12-31 C001553 1549 SCHERER UNIT 2, Generation, Attended 2023-12-31 C001553 PLL-I Power & Light - Large 2023-01-01 2023-12-31 C001553 1878 VOGTLE 230KV SWITCHING, Transmission, Unattended 2023-01-01 2023-12-31 C001553 180 BOLTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1859 VILLA RICA PRIMARY, Transmission, Unattended 2023-12-31 C001553 517 DUBLIN, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1879 VOGTLE 3&4 500KV, Generation, Attended 2023-01-01 2023-12-31 C001553 1763 THOMSON PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 ferc:HydraulicProductionPlantConventionalMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1567 SEWELL ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 500 DOLCO PACKAGING, Distribution, Unattended 2023-12-31 C001553 Increases (Decreases) from Sales of Donations Received from Stockholders 2023-01-01 2023-12-31 C001553 1597 SOCIAL CIRCLE PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1187 NASHVILLE #1, Distribution, Unattended 2023-12-31 C001553 948 KINGS BAY SOLAR (IC-391), Generation, Attended 2023-12-31 C001553 RLG Roadway Lighting Governmental 2023-01-01 2023-12-31 C001553 1080 MCINTOSH CT, Generation, Attended 2023-01-01 2023-12-31 C001553 1586 SKIDAWAY ISLAND, Distribution, Unattended 2023-12-31 C001553 RTHPLMI Real Time Pricing Hour Ahead - Power & Light Medium 2023-01-01 2023-12-31 C001553 633 FOLKSTON, Distribution, Unattended 2023-12-31 C001553 2024 ZIPPER, Distribution, Unattended 2023-01-01 2023-12-31 C001553 149 BIG A, Distribution, Unattended 2023-12-31 C001553 327 CLARKESVILLE, Distribution, Unattended 2023-12-31 C001553 1252 NORTHWEST WAYCROSS, Distribution, Unattended 2023-12-31 C001553 1329 PEACHTREE CORNERS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 241 BUFORD, Distribution, Unattended 2023-12-31 C001553 1779 TOM HUSTON PEANUT (Bakery), Distribution, Unattended 2023-12-31 C001553 1556 SCHERER UNIT 4, Generation, Attended 2023-01-01 2023-12-31 C001553 1921 WAVERLY PRIMARY, Transmission, Unattended 2023-12-31 C001553 901 JESSIE PORCH ROAD PM, Distribution, Unattended 2023-12-31 C001553 88 AUGUSTA AREA #1 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1520 SAINT MARYS, Distribution, Unattended 2023-12-31 C001553 Packaging Corporation of America, LU, 2023-01-01 2023-12-31 C001553 1460 REST HAVEN, Distribution, Unattended 2023-12-31 C001553 1152 MONTEZUMA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 864 INTERSTATE CENTRE, Distribution, Unattended 2023-12-31 C001553 57 AQUILLA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 358 2023-01-01 2023-12-31 C001553 FPL2014 - Exxon & Blackjack Florida Power & Light Florida Power & Light FNO N/A 11 2023-01-01 2023-12-31 C001553 1972 WILLOW RUN ROAD, Distribution, Unattended 2023-12-31 C001553 ferc:NitrogenOxideMember Allowances Used 2023-01-01 2023-12-31 C001553 North Georgia Hydro Miscellaneous Additions ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 Series 2020B - 3.70% 2023-01-01 2023-12-31 C001553 TOUSCFC Time of Use - Supplier Choice FPO 2023-01-01 2023-12-31 C001553 1650 SOUTHERN RAILWAY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1010 LOCKHEED MARTIN #1, Distribution, Unattended 2023-12-31 C001553 Customer Service Operations Cyber Security ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 424 CSX INTERMODAL (Fairburn), Distribution, Unattended 2023-01-01 2023-12-31 C001553 RTHTEOI Real Time Pricing Hour Ahead - Time Of Use - Energy Only 2023-01-01 2023-12-31 C001553 1754 THIELE KAOLIN (Sandersville), Distribution, Unattended 2023-01-01 2023-12-31 C001553 1318 PATTON SEED PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 43 AMERICUS, Transmission, Unattended 2023-12-31 C001553 1588 SLAPPEY DRIVE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1676 STATESBORO, Distribution, Unattended 2023-01-01 2023-12-31 C001553 ferc:TransmissionPlantMember ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 660 FOWLER STREET, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2021 YOSHIDA, Distribution, Unattended 2023-01-01 2023-12-31 C001553 367 COLONIAL PIPELINE (Dacula), Distribution, Unattended 2023-12-31 C001553 927 KELLOGGS SNACKS, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1084 MCMANUS, Generation, Attended 2023-12-31 C001553 1451 REIDS PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 368 COLONIAL PIPELINE (Dacula), Distribution, Unattended 2023-01-01 2023-12-31 C001553 700 GEORGIA PACIFIC (Brunswick), Distribution, Unattended 2023-01-01 2023-12-31 C001553 SUTA, Payroll Tax, Alabama, 2023-01-01 2023-12-31 C001553 1922 WAVERLY PRIMARY, Transmission, Unattended 2023-12-31 C001553 1964 WHITEWATER, Distribution, Unattended 2023-12-31 C001553 MCINTOSH (CT) Oil 2023-01-01 2023-12-31 C001553 51 ANTHONY PM, Distribution, Unattended 2023-12-31 C001553 1605 SOPERTON PRIMARY, Distribution, Unattended 2023-01-01 2023-12-31 C001553 2010 WYNNTON, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1057 MARTIN MARIETTA (Johns Creek), Distribution, Unattended 2023-01-01 2023-12-31 C001553 299 CERTAINTEED (Athens), Distribution, Unattended 2023-12-31 C001553 1323 PEACH ORCHARD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 BONAIRE 230 KV LN, 230, 11.07, 50533 2023-01-01 2023-12-31 C001553 Capital Maintenance / Asset Management ferc:ElectricUtilityMember 2023-12-31 C001553 362 2023-01-01 2023-12-31 C001553 Coweta 1st Series 2006 - Variable 2023-12-31 C001553 Burton (A) 2023-01-01 2023-12-31 C001553 29 ALCOVY ROAD, Transmission, Unattended 2023-01-01 2023-12-31 C001553 310 CHEROKEE ROAD, Transmission, Unattended 2023-12-31 C001553 1966 WILDER ROAD PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1763 THOMSON PRIMARY, Transmission, Unattended 2023-12-31 C001553 1922 WAVERLY PRIMARY, Transmission, Unattended 2023-01-01 2023-12-31 C001553 396 COOPER TIRE, Distribution, Unattended 2023-12-31 C001553 1167 MOULTRIE, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1445 RED TOP MOUNTAIN, Distribution, Unattended 2023-12-31 C001553 1319 PAUL WINNIE PM, Distribution, Unattended 2023-12-31 C001553 1772 TIN BRIDGE PD, Distribution, Unattended 2023-01-01 2023-12-31 C001553 Storm Damage 2023-01-01 2023-12-31 C001553 765 GREENWOOD PARK, Distribution, Unattended 2023-12-31 C001553 783 GWINNETT STREET, Distribution, Unattended 2023-12-31 C001553 245 BULL CREEK, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1450 REIDS, Distribution, Unattended 2023-12-31 C001553 Motor Vehicle Tag Fees, Other Taxes and Fees, 0,ferc:ElectricUtilityMember 2023-01-01 2023-12-31 C001553 1751 THIELE KAOLIN (Limestone Creek), Distribution, Unattended 2023-12-31 C001553 1761 THOMSON AREA #2 PM, Distribution, Unattended 2023-01-01 2023-12-31 C001553 1381 POTTERVILLE PM, Distribution, Unattended 2023-01-01 2023-12-31 utr:Btu iso4217:USD utr:kWh xbrli:pure utr:mi utr:g utr:kV utr:bbl iso4217:USD utr:Mcf iso4217:USD utr:kW iso4217:USD utr:T utr:kWh iso4217:USD utr:MMBTU utr:MW utr:MVA xbrli:shares iso4217:USD utr:bbl utr:MWh iso4217:USD utr:g iso4217:USD xbrli:shares utr:T iso4217:USD utr:Mcf utr:Btu utr:kWh iso4217:USD utr:MW utr:mi xbrli:pure

THIS FILING IS
Item 1: ☑ An Initial (Original) Submission OR ☐ Resubmission No.

# FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report
These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

Exact Legal Name of Respondent (Company) Georgia Power Company | Year/Period of Report End of: 2023 / Q4

## INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

## GENERAL INFORMATION

1. ### Purpose

   FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.

2. ### Who Must Submit

   Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

   Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
   1. one million megawatt hours of total annual sales,
   2. 100 megawatt hours of annual sales for resale,
   3. 500 megawatt hours of annual power exchanges delivered, or
   4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

3. ### What and Where to Submit

   1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
   2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
   3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
   4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

         Schedules | Pages
         Comparative Balance Sheet | 110-113
         Statement of Income | 114-117
         Statement of Retained Earnings | 118-119
         Statement of Cash Flows | 120-121
         Notes to Financial Statements | 122-123

   5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
   6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
   7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

4. ### When to Submit

   FERC Forms 1 and 3-Q must be filed by the following schedule:

   1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
   2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).

5. ### Where to Send Comments on Public Reporting Burden.

   The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

   Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

## GENERAL INSTRUCTIONS

1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

## EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
2. 'Person' means an individual or a corporation;
3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

## GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO. 1 REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent Georgia Power Company | 02 Year/ Period of Report End of: 2023 / Q4
03 Previous Name and Date of Change (If name changed during year) /
04 Address of Principal Office at End of Period (Street, City, State, Zip Code) 241 Ralph McGill Blvd, NE, Atlanta, GA 30308-3374
05 Name of Contact Person Kim Thomas | 06 Title of Contact Person Financial Accounting and Reporting Manager
07 Address of Contact Person (Street, City, State, Zip Code) 241 Ralph McGill Blvd, NE, Atlanta, GA 30308-3374
08 Telephone of Contact Person, Including Area Code 404-506-6297 | 09 This Report is An Original / A Resubmission (1) ☑ An Original (2) ☐ A Resubmission | 10 Date of Report (Mo, Da, Yr) 04/01/2024
Annual Corporate Officer Certification
The undersigned officer certifies that: I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.
01 Name Adam D. Houston
02 Title Vice President and Comptroller
| 03 Signature Adam D. Houston | 04 Date Signed (Mo, Da, Yr) 04/01/2024
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No. | Title of Schedule (a) | Reference Page No. (b) | Remarks (c)
| ScheduleIdentificationAbstract Identification | 1 |
| ScheduleListOfSchedulesAbstract List of Schedules | 2 |
1 | ScheduleGeneralInformationAbstract General Information | 101 |
2 | ScheduleControlOverRespondentAbstract Control Over Respondent | 102 |
3 | ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent | 103 |
4 | ScheduleOfficersAbstract Officers | 104 |
5 | ScheduleDirectorsAbstract Directors | 105 |
6 | ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates | 106 |
7 | ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year | 108 |
8 | ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet | 110 |
9 | ScheduleStatementOfIncomeAbstract Statement of Income for the Year | 114 |
10 | ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year | 118 |
12 | ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows | 120 |
12 | ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements | 122 |
13 | ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities | 122a |
14 | ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep | 200 |
15 | ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials | 202 |
16 | ScheduleElectricPlantInServiceAbstract Electric Plant in Service | 204 |
17 | ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others | 213 |
18 | ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use | 214 |
19 | ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric | 216 |
20 | ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant | 219 |
21 | ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies | 224 |
22 | ScheduleMaterialsAndSuppliesAbstract Materials and Supplies | 227 |
23 | ScheduleAllowanceInventoryAbstract Allowances | 228 |
24 | ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses | 230a |
25 | ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs | 230b |
26 | ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs | 231 |
27 | ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets | 232 |
28 | ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits | 233 |
29 | ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes | 234 |
30 | ScheduleCapitalStockAbstract Capital Stock | 250 |
31 | ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital | 253 |
32 | ScheduleCapitalStockExpenseAbstract Capital Stock Expense | 254b | None
33 | ScheduleLongTermDebtAbstract Long-Term Debt | 256 |
34 | ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax | 261 |
35 | ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year | 262 |
36 | ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits | 266 |
37 | ScheduleOtherDeferredCreditsAbstract Other Deferred Credits | 269 |
38 | ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property | 272 |
39 | ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property | 274 |
40 | ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other | 276 |
41 | ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities | 278 |
42 | ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues | 300 |
43 | ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1) | 302 | None
44 | ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules | 304 |
45 | ScheduleSalesForResaleAbstract Sales for Resale | 310 |
46 | ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses | 320 |
47 | SchedulePurchasedPowerAbstract Purchased Power | 326 |
48 | ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others | 328 |
49 | ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs | 331 | None
50 | ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others | 332 |
51 | ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric | 335 |
52 | ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405) | 336 |
53 | ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses | 350 |
54 | ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities | 352 |
55 | ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages | 354 |
56 | ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses | 356 | None
57 | ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements | 397 |
58 | SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services | 398 |
59 | ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load | 400 |
60 | ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load | 400a |
61 | ScheduleElectricEnergyAccountAbstract Electric Energy Account | 401a |
62 | ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output | 401b |
63 | ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics | 402 |
64 | ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics | 406 |
65 | SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics | 408 |
66 | ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages | 410 |
66.1 | ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants) | 414 |
66.2 | ScheduleEnergyStorageOperationsSmallPlantsAbstract Energy Storage Operations (Small Plants) | 419 |
67 | ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages | 422 |
68 | ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year | 424 |
69 | ScheduleSubstationsAbstract Substations | 426 |
70 | ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies | 429 |
71 | FootnoteDataAbstract Footnote Data | 450 |
| StockholdersReportsAbstract Stockholders' Reports (check appropriate box) |  |
| Stockholders' Reports Check appropriate box: ☑ Two copies will be submitted ☐ No annual report to stockholders is prepared |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Adam D. Houston Vice President and Comptroller 241 Ralph McGill Blvd, NE, Atlanta, GA 30308-3374
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: GA Date of Incorporation: 1930-06-26 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Electric light and power - Georgia
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
(a) Name of controlling corporation: The Southern Company (Southern Company), a Delaware corporation. (b) Extent of control: All common stock of respondent is owned by Southern Company.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No. | NameOfCompanyControlledByRespondent Name of Company Controlled (a) | CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b) | VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c) | FootnoteReferences Footnote Ref. (d)
1 | Southern Electric Generating Company | Public Utility | 50 | (a) (a)
2 | Piedmont-Forrest Corporation | Subsidiary established for the purpose of handling various real estate related transactions. | 100 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: FootnoteReferences
(a) 50.00% of Southern Electric Generating Company's capital stock is owned by Georgia Power Company and 50.00% is owned by Alabama Power Company.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No. | OfficerTitle Title (a) | OfficerName Name of Officer (b) | OfficerSalary Salary for Year (c) | DateOfficerIncumbencyStarted Date Started in Period (d) | DateOfficerIncumbencyEnded Date Ended in Period (e)
1 | Chairman, President and Chief Executive Officer | Christopher C. Womack | 223,325 |  | 2023-03-31
2 | Chairman, President and Chief Executive Officer | Kimberly S. Greene | 900,004 | 2023-03-31 |
3 | Executive Vice President, Chief Financial Officer, and Treasurer | Aaron P. Abramovitz | 422,441 |  |
4 | Executive Vice President External Affairs and Nuclear Development | Meredith M. Lackey | 517,115 |  |
5 | Senior Vice President General Counsel, Corporate Secretary, and CCO | Sterling A. Spainhour | 120,865 |  | 2023-04-01
6 | Senior Vice President General Counsel, Corporate Secretary, and CCO | David E. Slovensky | 409,832 | 2023-04-01 |
7 | Senior Vice President, Charitable Giving | Michael K. Anderson | 256,531 |  | 2023-09-08
8 | (a) Senior Vice President, Human Resources | Sloane Drake | 108,131 |  | 2023-03-31
9 | (b) Senior Vice President, Human Resources | Lindsay Hill | 318,300 | 2023-04-01 |
10 | (c) Senior Vice President and Senior Production Officer - East Production Group | Allen Reaves | 168,745 |  | 2023-03-31
11 | (d) Senior Vice President and Senior Production Officer - East Production Group | Roderick W. Anderson | 342,525 | 2023-04-01 |
12 | Senior Vice President, Transmission | Fran Forehand | 359,781 |  |
13 | Senior Vice President, Customer Strategy and Solutions | Bentina Terry | 394,776 |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: OfficerTitle
Salary is allocated to multiple companies.
(b) Concept: OfficerTitle
Salary is allocated to multiple companies.
(c) Concept: OfficerTitle
Salary is allocated to multiple companies.
(d) Concept: OfficerTitle
Salary is allocated to multiple companies.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No. | NameAndTitleOfDirector Name (and Title) of Director (a) | PrincipalBusinessAddress Principal Business Address (b) | MemberOfTheExecutiveCommittee Member of the Executive Committee (c) | ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1 | Kimberly S. Greene, Chairman, President and CEO | 241 Ralph McGill Blvd NE, BIN 10240 Atlanta, GA 30308 | true | true
2 | (a) Christopher C. Womack, Chairman, President and CEO | 241 Ralph McGill Blvd NE, BIN 10240 Atlanta, GA 30308 | false | false
3 | Mark L. Burns | 500 Gulfstream Road, Savannah, GA 31408 | false | false
4 | Jill Campbell | N/A | false | false
5 | (b) Shantella E. Cooper | Five Concourse Parkway, Suite 3000, Atlanta, GA, 30328 | false | false
6 | (c) Lawrence L. Gellerstedt, III | 3350 Riverwood Parkway Suite 400, Atlanta, GA 30339 | false | false
7 | Thomas M. Holder | 3300 Riverwood Pkwy, Ste. 1200, Atlanta, GA 30339 | false | false
8 | Kessel D. Stelling, Jr. | 1111 Bay Avenue, Suite 500, Columbus, GA 31901 | true | false
9 | Charles K. Tarbutton | 750 Sparta Road, Sandersville, GA 31082 | true | false
10 | Clyde C. Tuggle | 4473 Northside Parkway, Atlanta, GA. 30327 | true | false
11 | Andrew W. Evans | N/A | false | false
12 | Steven R. Ewing | N/A | false | false

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: NameAndTitleOfDirector
Retired effective March, 2023
(b) Concept: NameAndTitleOfDirector
Retired effective October, 2023
(c) Concept: NameAndTitleOfDirector
Retired effective February, 2023

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

INFORMATION ON FORMULA RATES
Does the respondent have formula rates? | ☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No. | RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a) | ProceedingDocketNumber FERC Proceeding (b)
1 | Georgia Power Company Rate Schedule Federal Energy Regulatory Commission (FERC) No. 793 | Initial docket not available on eLibrary
2 | Georgia Power Company Rate ScheduleFERC No. 833 | ER99-3051-000
3 | Georgia Power Company Rate ScheduleFERC No. 835 | ER02-1574-000
4 | Georgia Power Company Rate Schedule No. 850 | ER16-2672-000
5 | Tariff Volume No. 5, Southern Companies OATT | ER20-1734-006
6 | Cost Based Rate Tariff,Southern’s Tariff Volume No. 11 | ER10-2925-000
7 | Southern Company Services, Inc.Tariff Volume No. 13 | ER20-1735-002
8 | Southern Operating CompaniesRate Schedule No. 33 | ER19-1000-000
9 | Southern Company Services, Inc.Rate Schedule No. 138 | ER22-1820-001
10 | Georgia Power Company Rate Schedule No. 836 | ER24-457-000
11 | Georgia Power Company Rate Schedule No. 837 | ER24-457-000
12 | Georgia Power Company Rate Schedule No. 838 | ER24-457-000

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)? | ☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No. | AccessionNumber Accession No. (a) | DocumentDate Document Date / Filed Date (b) | DocketNumber Docket No. (c) | DescriptionOfFiling Description (d) | RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1 | 20211101-5254 | 11/01/2022 | ER10-203-000 | 2023 OATT Informational Filing | Tariff Volume No. 5, Southern Companies OATT
2 | 20230501-5592 | 05/01/2023 | ER10-203-000 | 2022 OATT True-Up Filing | Tariff Volume No. 5, Southern Companies OATT
3 | 20221101-5088 | 11/01/2022 | ER10-171-000 | 2023 Intercompany Interchange Contract Informational Filing | Southern Company Services, Inc. Rate Schedule No. 138
4 | 20221103-5192 | 11/03/2022 | ER10-171-000 | Errata to 2023 Intercompany Interchange Contract | Southern Company Services, Inc. Rate Schedule No. 138
5 | 20231121-5123 | 11/21/2023 | ER24-457-000 | 2023 Post-Retirement Benefits Other Than Pensions Filing | Georgia Power Company Rate Schedule Nos. 836, 837, and 838

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No. | PageNumberOfFormulaRateVariances Page No(s). (a) | ScheduleOfFormulaRateVariances Schedule (b) | ColumnOfFormulaRateVariances Column (c) | LineNumberOfFormulaRateVariances Line No. (d)
1 | None |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1. None
2. None
3. In March 2023, Georgia Power sold seven 46kV, four 69kV, ten 115kV, and two 230kV transmission lines and in September 2023, under Docket No. AC23-159-000, Georgia Power requested and the Commission approved proposed accounting entries to clear Account 102, Electric Plant Purchased or Sold for approximately $56 million.
4. None
5. None
6. The following obligations were incurred as a result of the issuance of securities pursuant to Federal Energy Regulatory Commission approval: Georgia Power Company issued commercial paper from time to time during the year ended December 31, 2023. The largest amount of such commercial paper outstanding at any given time during such period was approximately $811 million. In March 2023, Georgia Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a mutually agreed upon rate and payable on demand. In April 2023, Georgia Power borrowed an additional $150 million under the arrangement. In December 2023, Georgia Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a mutually agreed upon rate and payable on demand. The following obligations were incurred as a result of the issuance of securities pursuant to Georgia Public Service Commission approval: In March 2023, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased and were held by Georgia Power at December 31, 2022: • approximately $28 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), Second Series 2006; • approximately $89 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), Second Series 2009; • approximately $49 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), First Series 2012; • approximately $18 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), First Series 2013; and • $46 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 1996. In May 2023, Georgia Power issued $750 million aggregate principal amount of Series 2023A 4.65% Senior Notes due May 16, 2028 and $1.0 billion aggregate principal amount of Series 2023B 4.95% Senior Notes due May 17, 2033. In November 2023, Georgia Power issued $700 million aggregate principal amount of Series 2023C Floating Rate Senior Notes due May 8, 2025.
7. None
8. None
9. See Note 3 to the Financial Statements for a description of certain legal proceedings.
10. None
13. Effective January 16, 2023, Chimaobi Chijioke was elected as Vice President. Effective February 16, 2023, Larry L. Gellerstedt, III resigned as a Director. Effective March 31, 2023, Steven R. Ewing was elected as a Director. Effective March 31, 2023, Christopher C. Womack resigned as Chairman, President and Chief Executive Officer. Effective March 31, 2023, Kimberly S. Greene was elected as Chairman, President and Chief Executive Officer. Effective March 31, 2023, Sloane N. Drake resigned as Senior Vice President. Effective March 31, 2023, R. Allen Reaves, Jr. resigned as Senior Vice President. Effective April 1, 2023, Sterling A. Spainhour resigned as Senior Vice President, Corporate Secretary and Chief Compliance Officer. Effective April 1, 2023, Erin P. Harris resigned as Vice President. Effective April 1, 2023, David E. Slovensky was elected as Senior Vice President, Corporate Secretary and Chief Compliance Officer. Effective April 1, 2023, Lindsay R. Hill was elected as Senior Vice President. Effective April 1, 2023, Roderick W. Anderson was elected as Senior Vice President. Effective April 1, 2023, John B. Williams was elected as Senior Vice President. Effective April 1, 2023, Jennifer S. McNelly was elected as Vice President. Effective April 1, 2023, Erica McGill was elected as Vice President. Effective April 30, 2023, Kyle Leach resigned as Vice President. Effective April 30, 2023, David L. McKinney resigned as Senior Vice President. Effective May 13, 2023, Sarah P. Adams resigned as Vice President and Comptroller. Effective May 13, 2023, Adam D. Houston experienced a change in officer designation from Assistant Comptroller to Vice President and Comptroller. Effective May 13, 2023, Matthew Berrigan was elected as Assistant Comptroller. Effective September 1, 2023, Lisa J. Smith resigned as Senior Vice President. Effective September 8, 2023, Michael K. Anderson resigned as Senior Vice President. Effective October 16, 2023, Shantella E. Cooper resigned as Director. Effective November 18, 2023, Tyler M. Cook resigned as Vice President.
14. N/A

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No. | Title of Account (a) | Ref. Page No. (b) | Current Year End of Quarter/Year Balance (c) | Prior Year End Balance 12/31 (d)
1 | UtilityPlantAbstract UTILITY PLANT |  |  |
2 | UtilityPlant Utility Plant (101-106, 114) | 200 | 50,978,886,183 | 43,455,117,881
3 | ConstructionWorkInProgress Construction Work in Progress (107) | 200 | 4,987,468,923 | 8,120,609,322
4 | UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3) |  | 55,966,355,106 | 51,575,727,203
5 | AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) | 200 | 14,000,522,463 | 13,156,790,331
6 | UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5) |  | 41,965,832,643 | 38,418,936,872
7 | NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1) | 202 | 123,568,334 | 237,956,861
8 | NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2) |  | 246,947,277 | 225,452,810
9 | NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3) |  | 566,785,247 | 480,388,723
10 | SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4) |  | 45,418,490 |
11 | NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6) |  |  |
12 | AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) | 202 | 377,554,986 | 340,156,168
13 | NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12) |  | 605,164,362 | 603,642,226
14 | UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13) |  | 42,570,997,005 | 39,022,579,098
15 | OtherElectricPlantAdjustments Utility Plant Adjustments (116) |  |  |
16 | GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117) |  |  |
17 | OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS |  |  |
18 | NonutilityProperty Nonutility Property (121) |  | 159,439,589 | 116,883,892
19 | AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122) |  | 15,205,867 | 13,654,690
20 | InvestmentInAssociatedCompanies Investments in Associated Companies (123) |  | 12,105,898 | 11,172,731
21 | InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1) | 224 | 52,399,208 | 57,341,286
23 | NoncurrentPortionOfAllowances Noncurrent Portion of Allowances | 228 |  |
24 | OtherInvestments Other Investments (124) |  | 11,106,903 | 4,879,512
25 | SinkingFunds Sinking Funds (125) |  |  |
26 | DepreciationFund Depreciation Fund (126) |  |  |
27 | AmortizationFundFederal Amortization Fund - Federal (127) |  |  |
28 | OtherSpecialFunds Other Special Funds (128) |  | (a) 2,967,948,441 | (b) 2,696,338,317
29 | SpecialFunds Special Funds (Non Major Only) (129) |  |  |
30 | DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175) |  |  |
31 | DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176) |  | 9,825,805 | 6,344,516
32 | OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31) |  | 3,197,619,977 | 2,879,305,564
33 | CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS |  |  |
34 | CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130) |  |  |
35 | Cash Cash (131) |  | 9,236,353 | 9,462,364
36 | SpecialDeposits Special Deposits (132-134) |  | 37,201,180 | 60,000,000
37 | WorkingFunds Working Fund (135) |  |  |
38 | TemporaryCashInvestments Temporary Cash Investments (136) |  |  | 355,000,000
39 | NotesReceivable Notes Receivable (141) |  |  |
40 | CustomerAccountsReceivable Customer Accounts Receivable (142) |  | 1,540,769,397 | 737,129,340
41 | OtherAccountsReceivable Other Accounts Receivable (143) |  | 179,156,533 | 175,852,740
42 | AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) |  | 4,000,360 | 2,535,162
43 | NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145) |  |  |
44 | AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146) |  | 51,084,909 | 53,100,053
45 | FuelStock Fuel Stock (151) | 227 | 468,132,742 | 281,851,393
46 | FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152) | 227 | 4,961,210 | 2,315,874
47 | Residuals Residuals (Elec) and Extracted Products (153) | 227 |  |
48 | PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154) | 227 | 883,001,663 | 728,169,157
49 | Merchandise Merchandise (155) | 227 |  |
50 | OtherMaterialsAndSupplies Other Materials and Supplies (156) | 227 | 263,239 | 389,375
51 | NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157) | 202/227 |  |
52 | AllowanceInventoryAndWithheld Allowances (158.1 and 158.2) | 228 | 7,223,951 | 7,239,520
53 | NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances | 228 |  |
54 | StoresExpenseUndistributed Stores Expense Undistributed (163) | 227 | 12,811 | 45,306
55 | GasStoredCurrent Gas Stored Underground - Current (164.1) |  |  |
56 | LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) |  |  |
57 | Prepayments Prepayments (165) |  | 118,270,591 | 95,836,363
58 | AdvancesForGas Advances for Gas (166-167) |  |  |
59 | InterestAndDividendsReceivable Interest and Dividends Receivable (171) |  |  | 1,285,084
60 | RentsReceivable Rents Receivable (172) |  | 25,218,067 | 16,137,113
61 | AccruedUtilityRevenues Accrued Utility Revenues (173) |  | 309,903,728 | 342,459,403
62 | MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174) |  | 90,204,515 | 58,822,027
63 | DerivativeInstrumentAssets Derivative Instrument Assets (175) |  | 533,845 | 26,000
64 | DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175) |  |  |
65 | DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176) |  | 11,891,102 | 41,717,326
66 | DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176) |  | 9,825,805 | 6,344,516
67 | CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66) |  | 3,723,239,671 | 2,957,868,148
68 | DeferredDebitsAbstract DEFERRED DEBITS |  |  |
69 | UnamortizedDebtExpense Unamortized Debt Expenses (181) |  | 121,537,906 | 117,257,256
70 | ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1) | 230a |  |
71 | UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2) | 230b |  |
72 | OtherRegulatoryAssets Other Regulatory Assets (182.3) | 232 | 7,618,024,924 | 7,610,374,834
73 | PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183) |  | 26,106,826 | 25,728,060
74 | PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1) |  |  |
75 | OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2) |  |  |
76 | ClearingAccounts Clearing Accounts (184) |  | 681,863 | 872,501
77 | TemporaryFacilities Temporary Facilities (185) |  |  |
78 | MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186) | 233 | 1,580,154,688 | 2,378,737,375
79 | DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187) |  |  |
80 | ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188) | 352 |  |
81 | UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189) |  | 197,335,147 | 213,071,369
82 | AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190) | 234 | 1,504,090,951 | (c) 1,495,476,493
83 | UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191) |  |  |
84 | DeferredDebits Total Deferred Debits (lines 69 through 83) |  | 11,046,568,579 | 11,841,517,888
85 | AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84) |  | 60,538,425,232 | 56,701,270,698

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: OtherSpecialFunds
Other Special Funds (128) | December 31, 2023
Restricted Cash | $ | 28,657,712 |
External Trusts | 2,939,290,729 |
Total Other Special Funds (128) | $ | 2,967,948,441 |
(b) Concept: OtherSpecialFunds
Other Special Funds (128) | December 31, 2022
Restricted Cash | $ | 55,712,734 |
External Trusts | 2,640,625,583 |
Total Other Special Funds (128) | $ | 2,696,338,317 |
(c) Concept: AccumulatedDeferredIncomeTaxes
ACCUMULATED DEFERRED INCOME TAXES (ACCOUNT 190) | BALANCE AT BEG OF YEAR |  | BALANCE AT END OF YEAR
Accrual for Uncollectibles | $ | 645,749 |  |  | $ | 1,018,960 |
Accumulated Rate Refund Georgia Public Service Commission | 30,824,146 |  | 12.00 |
Affirmative Adjustments* | 8,478,950 |  | 8,478,950.00 |
Capacity Buybacks* | 7,630 |  | — |
Capitalized Purchase Power Agreement Southern Power Co | 8,472,722 |  | 8,878,525.00 |
Deferred Revenues - Electric | 54,237 |  | 981,932.00 |
Demand Side Management Recovery | 9,580,081 |  | 11,673,980.00 |
FAS 133 Mark to Market* | 7,763,311 |  | 7,776,485.00 |
Health Reimbursement Accrual | 587,397 |  | 598,744.00 |
Income Taxes Deferred - Electric | 243,576,200 |  | 252,848,015.00 |
Protected Gross Up EADIT | 552,719,580 |  | 530,655,047.00 |
Income Taxes Deferred - CWIP Electric | (18,292,275) |  | (8,376,711.00) |
Income Taxes Deferred - Non Electric* | 3,070,827 |  | (19,793,690.00) |
Income Taxes Deferred - CWIP Non Electric* | (39,575,884) |  | (16,158,001.00) |
Injuries & Damages Reserve | 3,862,585 |  | 696,625.00 |
Nuclear Construction Cost Recovery Over/Under Recovery | - |  | — |
Other Comprehensive Income - Hedge Settlement | 4,064,883 |  | 3,038,900.00 |
Other Basis Differences | 74,181,501 |  | 77,408,551.00 |
Accrued Liabilities - Electric | 110,588,151 |  | 109,516,969.00 |
Accrued Liabilities - Non Electric* | 15,461,181 |  | 16,445,346.00 |
Storm Damage | 22,214,683 |  | — |
Tax Credit Carry Forward - Electric | 346,558,564 |  | 363,710,569.00 |
Tax Credit Carry Forward - Non Electric* | 124,293,426 |  | 160,032,604.00 |
Unbilled Fuel Revenues | 23,051,473 |  | 31,714,873.00 |
Unprotected Gross Up Deficient EADIT NCCR | (36,712,625) |  | (37,055,734.00) |
| --------------------- |  | ---------------------
Total | $ | 1,495,476,493 |  |  | $ | 1,504,090,951 |
| --------------------- |  | ---------------------
*Other Income and Deductions |  |  |
Classification of Totals: |  |  |
Federal Income Tax | $ | 882,849,107 |  |  | $ | 828,576,722 |
State Income Tax | $ | 612,627,386 |  |  | $ | 675,514,229 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No. | Title of Account (a) | Ref. Page No. (b) | Current Year End of Quarter/Year Balance (c) | Prior Year End Balance 12/31 (d)
1 | ProprietaryCapitalAbstract PROPRIETARY CAPITAL |  |  |
2 | CommonStockIssued Common Stock Issued (201) | 250 | 398,473,175 | 398,473,175
3 | PreferredStockIssued Preferred Stock Issued (204) | 250 |  |
4 | CapitalStockSubscribed Capital Stock Subscribed (202, 205) |  |  |
5 | StockLiabilityForConversion Stock Liability for Conversion (203, 206) |  |  |
6 | PremiumOnCapitalStock Premium on Capital Stock (207) |  | 8,664,636 | 8,664,636
7 | OtherPaidInCapital Other Paid-In Capital (208-211) | 253 | 17,914,475,721 | 15,616,448,441
8 | InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212) | 252 |  |
9 | DiscountOnCapitalStock (Less) Discount on Capital Stock (213) | 254 |  |
10 | CapitalStockExpense (Less) Capital Stock Expense (214) | 254b |  |
11 | RetainedEarnings Retained Earnings (215, 215.1, 216) | 118 | 3,034,736,783 | 2,805,711,814
12 | UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1) | 118 | 35,899,208 | 40,729,734
13 | ReacquiredCapitalStock (Less) Reacquired Capital Stock (217) | 250 |  |
14 | NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218) |  |  |
15 | AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219) | 122(a)(b) | 9,477,463 | 12,479,411
16 | ProprietaryCapital Total Proprietary Capital (lines 2 through 15) |  | 21,382,772,060 | 18,857,548,389
17 | LongTermDebtAbstract LONG-TERM DEBT |  |  |
18 | Bonds Bonds (221) | 256 | 100,000,000 | 100,000,000
19 | ReacquiredBonds (Less) Reacquired Bonds (222) | 256 | 100,000,000 | 329,485,000
20 | AdvancesFromAssociatedCompanies Advances from Associated Companies (223) | 256 |  |
21 | OtherLongTermDebt Other Long-Term Debt (224) | 256 | 16,601,214,069 | 15,036,793,026
22 | UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225) |  | 2,578,134 | 2,719,713
23 | UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226) |  | 21,402,810 | 20,571,398
24 | LongTermDebt Total Long-Term Debt (lines 18 through 23) |  | 16,582,389,393 | 14,789,456,341
25 | OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES |  |  |
26 | ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227) |  | 962,010,262 | 1,073,056,879
27 | AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1) |  |  | 83,324,714
28 | AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2) |  | 56,079,551 | 38,648,814
29 | AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3) |  | 1,282,371,802 | 1,162,644,720
30 | AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4) |  |  |
31 | AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229) |  | 3,855,051 | 121,226,243
32 | LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities |  |  |
33 | LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges |  | 42,242,787 | 18,452,199
34 | AssetRetirementObligations Asset Retirement Obligations (230) |  | 5,665,310,299 | 6,034,809,600
35 | OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34) |  | 8,011,869,752 | 8,532,163,169
36 | CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES |  |  |
37 | NotesPayable Notes Payable (231) |  | 520,000,000 | 1,600,000,000
38 | AccountsPayable Accounts Payable (232) |  | 1,117,804,471 | 1,052,446,993
39 | NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233) |  | 810,595,000 |
40 | AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234) |  | 839,901,727 | 928,282,719
41 | CustomerDeposits Customer Deposits (235) |  | 249,667,033 | 251,630,642
42 | TaxesAccrued Taxes Accrued (236) | 262 | 581,916,137 | 508,090,352
43 | InterestAccrued Interest Accrued (237) |  | 175,033,552 | 156,625,169
44 | DividendsDeclared Dividends Declared (238) |  |  |
45 | MaturedLongTermDebt Matured Long-Term Debt (239) |  |  |
46 | MaturedInterest Matured Interest (240) |  |  |
47 | TaxCollectionsPayable Tax Collections Payable (241) |  | 28,768,959 | 23,654,376
48 | MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242) |  | 492,370,168 | 492,629,735
49 | ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243) |  | 152,189,061 | 166,831,743
50 | DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244) |  |  | 579,142
51 | LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities |  |  |
52 | DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245) |  | 124,070,993 | 61,651,880
53 | LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges |  | 42,242,787 | 18,452,199
54 | CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53) |  | 5,050,074,314 | 5,223,970,552
55 | DeferredCreditsAbstract DEFERRED CREDITS |  |  |
56 | CustomerAdvancesForConstruction Customer Advances for Construction (252) |  | 103,078,581 | 99,470,668
57 | AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255) | 266 | 325,679,523 | 318,833,007
58 | DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256) |  |  |
59 | OtherDeferredCredits Other Deferred Credits (253) | 269 | 229,202,535 | 268,464,320
60 | OtherRegulatoryLiabilities Other Regulatory Liabilities (254) | 278 | 3,331,057,051 | 3,409,276,739
61 | UnamortizedGainOnReacquiredDebt Unamortized Gain on Reacquired Debt (257) |  | 14,447 | 27,358
62 | AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281) | 272 | 529,573,839 | 564,996,931
63 | AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282) |  | 3,508,541,899 | 3,174,006,201
64 | AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283) |  | 1,484,171,838 | 1,463,057,023
65 | DeferredCredits Total Deferred Credits (lines 56 through 64) |  | 9,511,319,713 | 9,298,132,247
66 | LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65) |  | 60,538,425,232 | 56,701,270,698

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No. | Title of Account (a) | (Ref.) Page No. (b) | Total Current Year to Date Balance for Quarter/Year (c) | Total Prior Year to Date Balance for Quarter/Year (d) | Current 3 Months Ended - Quarterly Only - No 4th Quarter (e) | Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f) | Electric Utility Current Year to Date (in dollars) (g) | Electric Utility Previous Year to Date (in dollars) (h) | Gas Utiity Current Year to Date (in dollars) (i) | Gas Utility Previous Year to Date (in dollars) (j) | Other Utility Current Year to Date (in dollars) (k) | Other Utility Previous Year to Date (in dollars) (l)
1 | UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME |  |  |  |  |  |  |  |  |  |  |
2 | OperatingRevenues Operating Revenues (400) | 300 | 9,901,740,533 | 11,439,781,440 |  |  | 9,901,740,533 | 11,439,781,440 |  |  |  |
3 | OperatingExpensesAbstract Operating Expenses |  |  |  |  |  |  |  |  |  |  |
4 | OperationExpense Operation Expenses (401) | 320 | 4,310,438,388 | 6,099,396,772 |  |  | 4,310,438,388 | 6,099,396,772 |  |  |  |
5 | MaintenanceExpense Maintenance Expenses (402) | 320 | 503,403,501 | 702,935,280 |  |  | 503,403,501 | 702,935,280 |  |  |  |
6 | DepreciationExpense Depreciation Expense (403) | 336 | 1,335,454,797 | 1,106,480,748 |  |  | 1,335,454,797 | 1,106,480,748 |  |  |  |
7 | DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1) | 336 | 29,215,684 | 38,776,261 |  |  | 29,215,684 | 38,776,261 |  |  |  |
8 | AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405) | 336 | 63,664,133 | 50,002,191 |  |  | 63,664,133 | 50,002,191 |  |  |  |
9 | AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406) | 336 | 642,691 | 640,752 |  |  | 642,691 | 640,752 |  |  |  |
10 | AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407) |  |  |  |  |  |  |  |  |  |  |
11 | AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2) |  |  |  |  |  |  |  |  |  |  |
12 | RegulatoryDebits Regulatory Debits (407.3) |  | 340,934,732 | 327,779,378 |  |  | 340,934,732 | 327,779,378 |  |  |  |
13 | RegulatoryCredits (Less) Regulatory Credits (407.4) |  | 315,146,948 | 314,411,175 |  |  | 315,146,948 | 314,411,175 |  |  |  |
14 | TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1) | 262 | 539,316,945 | 526,370,084 |  |  | 539,316,945 | 526,370,084 |  |  |  |
15 | IncomeTaxesOperatingIncome Income Taxes - Federal (409.1) | 262 | 207,197,765 | 50,695,948 |  |  | 207,197,765 | 50,695,948 |  |  |  |
16 | IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1) | 262 | 55,563,409 | 42,249,407 |  |  | 55,563,409 | 42,249,407 |  |  |  |
17 | ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1) | 234, 272 | 784,036,268 | 908,876,961 |  |  | 784,036,268 | 908,876,961 |  |  |  |
18 | ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1) | 234, 272 | 579,857,490 | 631,659,071 |  |  | 579,857,490 | 631,659,071 |  |  |  |
19 | InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4) | 266 | 10,981,079 | 8,938,554 |  |  | 10,981,079 | 8,938,554 |  |  |  |
20 | GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6) |  | 928,305 | 742,644 |  |  | 928,305 | 742,644 |  |  |  |
21 | LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7) |  |  | 6,984 |  |  |  | 6,984 |  |  |  |
22 | GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8) |  | 103,403 | 221 |  |  | 103,403 | 221 |  |  |  |
23 | LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9) |  |  |  |  |  |  |  |  |  |  |
24 | AccretionExpense Accretion Expense (411.10) |  | 230,524,826 | 231,052,096 |  |  | 230,524,826 | 231,052,096 |  |  |  |
25 | UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24) |  | 7,493,375,914 | 9,129,511,197 |  |  | 7,493,375,914 | 9,129,511,197 |  |  |  |
27 | NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25) |  | 2,408,364,619 | 2,310,270,243 |  |  | 2,408,364,619 | 2,310,270,243 |  |  |  |
28 | OtherIncomeAndDeductionsAbstract Other Income and Deductions |  |  |  |  |  |  |  |  |  |  |
29 | OtherIncomeAbstract Other Income |  |  |  |  |  |  |  |  |  |  |
30 | NonutilityOperatingIncomeAbstract Nonutilty Operating Income |  |  |  |  |  |  |  |  |  |  |
31 | RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415) |  | 223,850,482 | 142,879,488 |  |  |  |  |  |  |  |
32 | CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416) |  | 181,276,630 | 116,825,741 |  |  |  |  |  |  |  |
33 | RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417) |  |  | 19,543 |  |  |  |  |  |  |  |
34 | ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1) |  | 2,966,713 | 2,343,608 |  |  |  |  |  |  |  |
35 | NonoperatingRentalIncome Nonoperating Rental Income (418) |  | 17,979,149 | 17,200,000 |  |  |  |  |  |  |  |
36 | EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1) | 119 | 7,109,580 | 6,260,005 |  |  |  |  |  |  |  |
37 | InterestAndDividendIncome Interest and Dividend Income (419) |  | 11,587,161 | 10,156,495 |  |  |  |  |  |  |  |
38 | AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1) |  | 147,082,877 | 156,412,191 |  |  |  |  |  |  |  |
39 | MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421) |  | 6,041,849 | 20,132,833 |  |  |  |  |  |  |  |
40 | GainOnDispositionOfProperty Gain on Disposition of Property (421.1) |  | 25,980,365 | 17,641,954 |  |  |  |  |  |  |  |
41 | OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40) |  | 255,388,120 | 251,533,160 |  |  |  |  |  |  |  |
42 | OtherIncomeDeductionsAbstract Other Income Deductions |  |  |  |  |  |  |  |  |  |  |
43 | LossOnDispositionOfProperty Loss on Disposition of Property (421.2) |  | 4,028,126 | 109,916 |  |  |  |  |  |  |  |
44 | MiscellaneousAmortization Miscellaneous Amortization (425) |  | 16,487 | 50,021 |  |  |  |  |  |  |  |
45 | Donations Donations (426.1) |  | 8,069,609 | 50,576,543 |  |  |  |  |  |  |  |
46 | LifeInsurance Life Insurance (426.2) |  | 245,535 | 237,374 |  |  |  |  |  |  |  |
47 | Penalties Penalties (426.3) |  | 201,218 | 11,187 |  |  |  |  |  |  |  |
48 | ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4) |  | 11,313,873 | 19,181,175 |  |  |  |  |  |  |  |
49 | OtherDeductions Other Deductions (426.5) |  | 80,026,363 | 199,850,003 |  |  |  |  |  |  |  |
50 | OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49) |  | 56,642,585 | 269,541,471 |  |  |  |  |  |  |  |
51 | TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions |  |  |  |  |  |  |  |  |  |  |
52 | TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2) | 262 | 15,001,791 | 15,129,366 |  |  |  |  |  |  |  |
53 | IncomeTaxesFederal Income Taxes-Federal (409.2) | 262 | 2,354,936 | 12,665,915 |  |  |  |  |  |  |  |
54 | IncomeTaxesOther Income Taxes-Other (409.2) | 262 | 18,126,521 | 62,876,965 |  |  |  |  |  |  |  |
55 | ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2) | 234, 272 | 114,431,710 | 241,478,463 |  |  |  |  |  |  |  |
56 | ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2) | 234, 272 | 112,239,674 | 165,943,651 |  |  |  |  |  |  |  |
57 | InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5) |  |  |  |  |  |  |  |  |  |  |
58 | InvestmentTaxCredits (Less) Investment Tax Credits (420) |  |  |  |  |  |  |  |  |  |  |
59 | TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58) |  | 3,287,630 | 15,121,298 |  |  |  |  |  |  |  |
60 | NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59) |  | 315,318,335 | 33,129,609 |  |  |  |  |  |  |  |
61 | InterestChargesAbstract Interest Charges |  |  |  |  |  |  |  |  |  |  |
62 | InterestOnLongTermDebt Interest on Long-Term Debt (427) |  | 582,910,407 | 480,819,503 |  |  |  |  |  |  |  |
63 | AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428) |  | 11,799,979 | 10,671,535 |  |  |  |  |  |  |  |
64 | AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1) |  | 15,787,836 | 21,418,808 |  |  |  |  |  |  |  |
65 | AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429) |  | 116,787 | 165,291 |  |  |  |  |  |  |  |
66 | AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1) |  | 37,704 |  |  |  |  |  |  |  |  |
67 | InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430) |  | 13,616,515 | 2,312,819 |  |  |  |  |  |  |  |
68 | OtherInterestExpense Other Interest Expense (431) |  | 90,653,443 | 34,594,807 |  |  |  |  |  |  |  |
69 | AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) |  | 70,545,178 | 85,865,313 |  |  |  |  |  |  |  |
70 | NetInterestCharges Net Interest Charges (Total of lines 62 thru 69) |  | 644,068,511 | 463,786,868 |  |  |  |  |  |  |  |
71 | IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70) |  | 2,079,614,443 | 1,813,353,766 |  |  |  |  |  |  |  |
72 | ExtraordinaryItemsAbstract Extraordinary Items |  |  |  |  |  |  |  |  |  |  |
73 | ExtraordinaryIncome Extraordinary Income (434) |  |  |  |  |  |  |  |  |  |  |
74 | ExtraordinaryDeductions (Less) Extraordinary Deductions (435) |  |  |  |  |  |  |  |  |  |  |
75 | NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74) |  |  |  |  |  |  |  |  |  |  |
76 | IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3) | 262 | 0 |  |  |  |  |  |  |  |  |
77 | ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76) |  |  |  |  |  |  |  |  |  |  |
78 | NetIncomeLoss Net Income (Total of line 71 and 77) |  | 2,079,614,443 | 1,813,353,766 |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No. | Item (a) | Contra Primary Account Affected (b) | Current Quarter/Year Year to Date Balance (c) | Previous Quarter/Year Year to Date Balance (d)
| UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216) |  |  |
1 | UnappropriatedRetainedEarnings Balance-Beginning of Period |  | 2,734,899,204 | 2,620,046,265
2 | ChangesAbstract Changes |  |  |
3 | AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439) |  |  |
4 | AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit |  |  |
9 | AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439) |  |  |
10 | AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit |  |  |
15 | AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439) |  |  |
16 | BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1) |  | 2,072,504,863 | 1,807,093,761
17 | AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436) |  |  |
17.1 | AppropriationsOfRetainedEarnings |  | 3,395,345 | 7,906,804
22 | AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436) |  | 3,395,345 | 7,906,804
23 | DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437) |  |  |
29 | DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437) |  |  |
30 | DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438) |  |  |
30.1 | DividendsDeclaredCommonStock (a) Common Stock (all owned by Southern Company) |  | 1,855,420,000 | 1,690,680,000
36 | DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438) |  | 1,855,420,000 | 1,690,680,000
37 | TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings |  | 11,940,106 | 6,345,982
38 | UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37) |  | 2,960,528,828 | 2,734,899,204
39 | AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215) |  |  |
45 | AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215) |  |  |
| AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1) |  |  |
46 | AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1) |  | 74,207,955 | 70,812,610
47 | AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46) |  | 74,207,955 | 70,812,610
48 | RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1) |  | 3,034,736,783 | 2,805,711,814
| UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly) |  |  |
49 | UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit) |  | 40,729,734 | 40,815,711
50 | EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1) |  | 7,109,580 | 6,260,005
51 | DividendsReceived (Less) Dividends Received (Debit) |  | 11,940,106 | 6,345,982
52 | ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year |  |  |
53 | UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52) |  | 35,899,208 | 40,729,734

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DividendsDeclaredCommonStockDescription
Note 1: Dividend Declarations
| 2023 | 2022
Common Stock | $ | 1,855,420,000 |  | $ | 1,690,680,000 |
All common stock of the respondent is owned by Southern Company.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No. | Description (See Instructions No.1 for explanation of codes) (a) | Current Year to Date Quarter/Year (b) | Previous Year to Date Quarter/Year (c)
1 | NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities |  |
2 | NetIncomeLoss Net Income (Line 78(c) on page 117) | 2,079,614,443 | 1,813,353,766
3 | NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income: |  |
4 | DepreciationAndDepletion Depreciation and Depletion | 1,524,369,889 | 1,174,053,127
5 | NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details) |  |
5.1 | NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of |  |
5.2 | NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Nuclear Fuel | 144,146,696 | 122,644,692
5.3 | NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other | 329,772,708 | 321,827,717
8 | DeferredIncomeTaxesNet Deferred Income Taxes (Net) | 184,932,165 | 313,807,901
9 | InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net) | 10,457,571 | 30,006,247
10 | NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables | 250,254,426 | 286,814,563
11 | NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory | 342,187,959 | 116,258,117
12 | NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory | 15,569 | 15,280
13 | NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses | 76,118,794 | 611,527,253
14 | NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets | 48,614,816 | 63,070,138
15 | NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities | 123,553,797 | 69,034,429
16 | AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction | 147,082,877 | 156,412,191
17 | UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies | 7,109,580 | 6,260,006
18 | OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote): |  |
18.1 | OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote): |  |
18.2 | OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Estimated Loss on Plant Vogtle Units 3 and 4 | 67,510,140 | 183,348,000
18.3 | OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other, Net | (a) 914,478,787 | (f) 2,094,169,429
22 | NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21) | 2,796,906,717 | 2,042,774,244
24 | CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities: |  |
25 | ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land): |  |
26 | GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel) | 4,835,206,002 | 3,921,626,054
27 | GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel | 143,710,608 | 141,172,992
28 | GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant |  |
29 | GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant | 35,358,116 |
30 | AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction | 147,082,877 | 156,412,191
31 | OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote): |  |
31.1 | OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote): |  |
34 | CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33) | 4,867,191,849 | 3,906,386,855
36 | AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d) |  |
37 | ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d) |  |
39 | InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies | 3,048,072 | 4,135,061
40 | ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies |  |
41 | DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to) |  |
42 | DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies |  |
44 | PurchaseOfInvestmentSecurities Purchase of Investment Securities (a) |  |
45 | ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a) |  |
46 | LoansMadeOrPurchased Loans Made or Purchased |  |
47 | CollectionsOnLoans Collections on Loans |  |
49 | NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables | 6,649,442 | 13,810,568
50 | NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory |  |
51 | NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation |  |
52 | NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses | 43,767,779 | 200,179,495
53 | OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote): |  |
53.1 | OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Fixed Assets | 59,408,086 | 55,994,379
53.2 | OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other (provide details in footnote): | (b) 363,754,491 | (g) 290,611,212
57 | CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55) | 5,124,169,105 | 3,958,769,822
59 | CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities: |  |
60 | ProceedsFromIssuanceAbstract Proceeds from Issuance of: |  |
61 | ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b) | 2,679,485,000 | 1,700,000,000
62 | ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock |  |
63 | ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock |  |
64 | OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote): |  |
64.1 | OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Other (provide details in footnote): |  |
64.2 | OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Short-Term Borrowings | 350,000,000 | 2,100,000,000
66 | NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c) | 810,595,000 |
67 | OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |  |
67.1 | DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |  |
67.2 | DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Capital Contributions from Parent Company | 2,290,884,036 | 1,470,616,486
70 | CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69) | 6,130,964,036 | 5,270,616,486
72 | PaymentsForRetirementAbstract Payments for Retirement of: |  |
73 | PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b) | 885,578,957 | 665,868,550
74 | PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock |  |
75 | PaymentsForRetirementOfCommonStockFinancingActivities Common Stock |  |
76 | OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): |  |
76.1 | DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): | (c) 37,782,543 | (h) 50,620,448
76.2 | DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Short-Term Borrowings | 1,430,000,000 | 500,000,000
78 | NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c) |  |
80 | DividendsOnPreferredStock Dividends on Preferred Stock |  |
81 | DividendsOnCommonStock Dividends on Common Stock | 1,855,420,000 | 1,690,680,000
83 | CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81) | 1,922,182,536 | 2,363,447,488
85 | NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents |  |
86 | NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83) | 405,079,852 | 447,451,910
88 | CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period | (d) 480,175,098 | 32,723,188
90 | CashAndCashEquivalents Cash and Cash Equivalents at End of Period | (e) 75,095,246 | (i) 480,175,098

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Other Operating Activities | Year-to-Date December 2023
Asset Retirement Obligation Settlements | $ | (303,619,993) |
Pension, Postretirement, & Other Employee Benefits | (270,388,159) |
Retail Fuel Cost Under Recovery - Long-Term | (156,545,636) |
Storm Damage Reserve | (83,324,714) |
Contract Assets | (32,751,608) |
Plant Dismantlement Costs Reclassed from Cost of Removal | (29,667,329) |
Net (Gain)/Loss on Asset Sales | (21,862,926) |
Spent Fuel Dry Cask Storage | (12,802,544) |
Prepaid Income Taxes - Federal | (7,725,290) |
Jobbing Holding (Various) | (6,693,142) |
Noncash Vogtle 3&4 AFUDC-Debt | (6,300,500) |
SNC Inventory Progress Payments | (5,052,218) |
Prepaid Income Taxes - State | (4,519,120) |
Distributed Generation Collateral | (3,871,964) |
Worker's Comp Reserve | (3,654,458) |
Prepayments | (3,550,268) |
Hedge Settlements | (2,548,313) |
Bank Line of Credit Fees | (2,501,844) |
Outdoor Lighting NEC Jobbing | (2,329,500) |
Stock Option Expense | 15,468,725 |
Noncash V3 Online Station Service & Gross Generation | 13,467,806 |
SEGCO Dividends | 13,158,207 |
Other Operating | 3,136,001 |
Total Other Operating Activities | $ | (914,478,787) |
(b) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other Investing Activities | Year-to-Date December 2023
Nuclear Decommissioning Trust (NDT) Fund Purchases | $ | (841,384,032) |
Cost of Removal, Net of Salvage | (278,747,013) |
Long-Term Service Agreement | (49,372,996) |
Preliminary Survey and Investigation | (5,326,925) |
Oconee 1 LLC Loan | (5,000,000) |
Prepaid Construction Insurance | (4,320,935) |
NDT Fund Sales | 820,904,966 |
Other Investing | (507,556) |
Total Other Investing Activities | $ | (363,754,491) |
(c) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other Financing Activities | Year-to-Date December 2023
Debt Issuance Costs | $ | (16,963,654) |
Finance Lease Redemptions | (16,121,739) |
Performance Shares Payroll Taxes | (8,325,480) |
Customer Advances | 3,607,913 |
Other Financing | 20,417 |
Total Other Financing Activities | $ | (37,782,543) |
(d) Concept: CashAndCashEquivalents
| Year-to-Date December 2022
Supplemental Cash Flow Information |
Cash Paid During the Period for: |
Interest | $ | 432,378,785 |
Income Taxes (Net of Refunds) | 29,666,504 |
Noncash Transactions: |
Accrued Property Additions at End of Period | $ | 626,286,409 |
Right-of-Use Assets Obtained Under Operating Leases | 16,755,953 |
Right-of-Use Assets Obtained Under Finance Leases | 115,771,258 |
Balance Sheet |
Other Special Funds - Restricted Cash (128) | $ | 55,712,734 |
Cash (131) | 9,462,364 |
Other Special Deposits - Restricted Cash (134) | 60,000,000 |
Working Funds (135) | — |
Temporary Cash Investments (136) | 355,000,000 |
Cash Flow Cash, Cash Equivalents, and Restricted Cash | $ | 480,175,098 |
(e) Concept: CashAndCashEquivalents
| Year-to-Date December 2023
Supplemental Cash Flow Information |
Cash Paid During the Period for: |
Interest | $ | 592,462,994 |
Income Taxes (Net of Refunds) | 219,591,780 |
Noncash Transactions: |
Accrued Property Additions at End of Period | $ | 680,266,331 |
Right-of-Use Assets Obtained Under Operating Leases | 25,961,030 |
Right-of-Use Assets Obtained Under Finance Leases | 18,061,907 |
Balance Sheet |
Other Special Funds - Restricted Cash (128) | $ | 28,657,712 |
Cash (131) | 9,236,353 |
Other Special Deposits - Restricted Cash (134) | 37,201,181 |
Working Funds (135) | — |
Temporary Cash Investments (136) | — |
Cash Flow Cash, Cash Equivalents, and Restricted Cash | $ | 75,095,246 |
(f) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Other Operating Activities | Year-to-Date December 2022
Retail Fuel Cost Under Recovery - Long-Term | $ | (1,646,056,735) |
Pension, Postretirement, & Other Employee Benefits | (238,137,922) |
Asset Retirement Obligation Settlements | (212,361,577) |
Return of Utility Scale Solar PPA Collateral | (36,167,915) |
Plant Dismantlement Costs Reclassed from Cost of Removal | (29,738,716) |
Contract Assets | (26,100,427) |
Net (Gain)/Loss on Asset Sales | (17,633,822) |
Prepaid Income Taxes - State | (11,979,474) |
PPA Performance Security | (8,763,885) |
Spent Fuel Dry Cask Storage | (6,597,983) |
Transmission Upgrade Charge for PPA | (5,450,000) |
SNC Inventory Progress Payments | (4,815,565) |
Storm Damage Reserve | 83,324,714 |
Hedge Settlements | 31,203,015 |
Stock Option Expense | 13,467,320 |
Nonaffiliated Storm Assistance Billing | 10,844,194 |
SEGCO Dividends | 6,921,949 |
Distributed Generation Collateral | 4,781,802 |
Other Operating | (908,402) |
Total Other Operating Activities | $ | (2,094,169,429) |
(g) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other Investing Activities | Year-to-Date December 2022
Nuclear Decommissioning Trust (NDT) Fund Purchases | $ | (770,276,049) |
Cost of Removal, Net of Salvage | (274,294,367) |
Long-Term Service Agreement | (43,841,685) |
Non-Utility Property | (37,744,451) |
Preliminary Survey and Investigation | (11,802,714) |
Prepaid Construction Insurance | (3,029,426) |
NDT Fund Sales | 758,373,122 |
Contributions in Aid of Construction | 92,452,275 |
Other Investing | (447,917) |
Total Other Investing Activities | $ | (290,611,212) |
(h) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other Financing Activities | Year-to-Date December 2022
Debt Issuance Costs | $ | (24,773,480) |
Finance Lease Redemptions | (14,568,782) |
Performance Shares Payroll Taxes | (11,278,186) |
Total Other Financing Activities | $ | (50,620,448) |
(i) Concept: CashAndCashEquivalents
| Year-to-Date December 2022
Supplemental Cash Flow Information |
Cash Paid During the Period for: |
Interest | $ | 432,378,785 |
Income Taxes (Net of Refunds) | 29,666,504 |
Noncash Transactions: |
Accrued Property Additions at End of Period | $ | 626,286,409 |
Right-of-Use Assets Obtained Under Operating Leases | 16,755,953 |
Right-of-Use Assets Obtained Under Finance Leases | 115,771,258 |
Balance Sheet |
Other Special Funds - Restricted Cash (128) | $ | 55,712,734 |
Cash (131) | 9,462,364 |
Other Special Deposits - Restricted Cash (134) | 60,000,000 |
Working Funds (135) | — |
Temporary Cash Investments (136) | 355,000,000 |
Cash Flow Cash, Cash Equivalents, and Restricted Cash | $ | 480,175,098 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

NOTES TO FINANCIAL STATEMENTS
Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
Notes to the Financial Statements for The Southern Company and Subsidiary Companies Alabama Power Company Georgia Power Company Mississippi Power Company Southern Power Company and Subsidiary Companies Southern Company Gas and Subsidiary Companies Index to the Combined Notes to Financial Statements
Note |  | Page
1 | Summary of Significant Accounting Policies | II-2
2 | Regulatory Matters | II-16
4 | Revenue from Contracts with Customers | II-44
5 | Property, Plant, and Equipment | II-47
6 | Asset Retirement Obligations | II-51
7 | Consolidated Entities and Equity Method Investments | II-55
8 | Financing | II-58
9 | Leases | II-66
10 | Income Taxes | II-73
11 | Retirement Benefits | II-80
12 | Stock Compensation | II-107
13 | Fair Value Measurements | II-109
14 | Derivatives | II-116
15 | Acquisitions and Dispositions | II-125
16 | Segment and Related Information | II-127
3 | Contingencies, Commitments, and Guarantees | II-38
17 | Subsequent Events |
Index to Applicable Notes to Financial Statements by Registrant The following notes to the financial statements are a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. The list below indicates the Registrants to which each note applies.
Registrant | Applicable Notes
Southern Company | 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16
Alabama Power | 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15
Georgia Power | 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14
Mississippi Power | 1, 2, 3, 4, 5, 6, 8, 9, 10, 11, 12, 13, 14
Southern Power | 1, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15
Southern Company Gas | 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES These financial statements were prepared in accordance with the accounting requirements of the Federal Energy Regulatory Commission (FERC) as set forth in the applicable Uniform System of Accounts and published accounting releases, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States (GAAP). These requirements as they relate to the attached financial statements differ from GAAP primarily in: –The classification of the components of: –Accumulated deferred income taxes –Uncertain tax positions –Certain miscellaneous current and accrued liabilities –Prepaid assets –Pension and post-retirement benefit obligations –Maturities of long-term debt –Deferred debits and credits –Certain regulatory assets and liabilities –The presentation of: –Majority-owned subsidiaries and certain other investments –Certain other cost of removal obligations –Post-retirement defined benefit plans –Unamortized debt expense –Unamortized discounts for certain short-term debt –Taxes applicable to other income and deductions –Gains and losses on disposition of property –Line of credit commitment fees and associated expenses –Certain disallowances on operations and maintenance expenses –The fair value amounts of derivative assets and liabilities –ASU 2016-02, Leases (Topic 842) –ASU 2018-15, Intangibles – Goodwill and Other – Internal-Use Software (Topic 350) –ASC 606, Revenue from Contracts with Customers –Establishment and/or amortization of regulatory assets and liabilities –Assets held for sale –Comparative presentation The Notes to the Financial Statements have been prepared in conformity with GAAP. Accordingly, certain Notes are not prepared on the same basis as the financial statements presented herein. Management has evaluated the impact of events occurring after December 31, 2023 up to February 14, 2024, the date that Georgia Power's GAAP financial statements were issued and has updated such evaluation for disclosure purposes through April 1, 2024 as it pertains to Georgia Power. These financial statements include all necessary adjustments and disclosures from these evaluations. General Southern Company is the parent company of three traditional electric operating companies, as well as Southern Power, Southern Company Gas, SCS, Southern Linc, Southern Holdings, Southern Nuclear, PowerSecure, and other direct and indirect subsidiaries. The traditional electric operating companies – Alabama Power, Georgia Power, and Mississippi Power – are vertically integrated utilities providing electric service in three Southeastern states. Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through natural gas distribution utilities, including Nicor Gas (Illinois), Atlanta Gas Light (Georgia), Virginia Natural Gas, and Chattanooga Gas (Tennessee). Southern Company Gas is also involved in several other complementary businesses including gas pipeline investments and gas marketing services. Prior to the sale of Sequent on July 1, 2021, these businesses also included wholesale gas services. SCS, the system service company, provides, at cost, specialized services to Southern Company and its subsidiary companies. Southern Linc provides digital wireless communications for use by Southern Company and its subsidiary companies and also markets these services to the public and provides fiber optics services within the Southeast. Southern Holdings is an intermediate holding company subsidiary. Southern Nuclear operates and provides services to the Southern Company system's nuclear power plants, including Alabama Power's Plant Farley and Georgia Power's Plant Hatch and Plant Vogtle Units 1 through 3, and is currently managing construction and start-up of Plant Vogtle Unit 4. PowerSecure develops distributed energy and resilience solutions and deploys microgrids for commercial, industrial, governmental, and utility customers. See Note 15 for information regarding the sale of Sequent. The Registrants' financial statements reflect investments in subsidiaries on a consolidated basis. Intercompany transactions have been eliminated in consolidation. The equity method is used for investments in entities in which a Registrant has significant influence but does not have control and for VIEs where a Registrant has an equity investment but is not the primary beneficiary. Southern Power has controlling ownership in certain legal entities for which the contractual provisions represent profit-sharing arrangements because the allocations of cash distributions and tax benefits are not based on fixed ownership percentages. For these arrangements, the noncontrolling interest is accounted for under a balance sheet approach utilizing the HLBV method. The HLBV method calculates each partner's share of income based on the change in net equity the partner can legally claim in a HLBV at the end of the period compared to the beginning of the period. See "Variable Interest Entities" herein and Note 7 for additional information. The traditional electric operating companies, Southern Power, certain subsidiaries of Southern Company Gas, and certain other subsidiaries are subject to regulation by the FERC, and the traditional electric operating companies and the natural gas distribution utilities are also subject to regulation by their respective state PSCs or other applicable state regulatory agencies. As such, the respective financial statements of the applicable Registrants reflect the effects of rate regulation in accordance with GAAP and comply with the accounting policies and practices prescribed by relevant state PSCs or other applicable state regulatory agencies. The preparation of financial statements in conformity with GAAP requires the use of estimates, and the actual results may differ from those estimates. Certain prior years' data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the Registrants' results of operations, financial position, or cash flows. Recently Adopted Accounting Standards In 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04) providing temporary guidance to ease the potential burden in accounting for reference rate reform primarily resulting from the discontinuation of LIBOR, which began phasing out on December 31, 2021. The discontinuation date of the overnight 1-, 3-, 6-, and 12-month tenors of LIBOR was June 30, 2023, which was beyond the original effective date of ASU 2020-04; therefore, in December 2022, the FASB issued ASU 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 (ASU 2022-06) to defer the sunset date of ASU 2020-04 from December 31, 2022 to December 31, 2024. The amendments were elective and applied to all entities that have contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued. The guidance (i) simplified accounting analyses under current GAAP for contract modifications; (ii) simplified the assessment of hedge effectiveness and allows hedging relationships affected by reference rate reform to continue; and (iii) allowed a one-time election to sell or transfer debt securities classified as held to maturity that reference a rate affected by reference rate reform. An entity could elect to apply the amendments prospectively from March 12, 2020 through December 31, 2024 by accounting topic. The Registrants elected to apply the amendments to modifications of debt and derivative arrangements that meet the scope of ASU 2020-04 and ASU 2022-06. Certain provisions in PPAs at Southern Power included references to LIBOR. Contract amendments have been executed to change to a SOFR-based interest rate. Southern Power adopted and applied the practical expedients guidance to these PPAs. Additionally, the Registrants referenced LIBOR for certain debt and hedging arrangements. As of July 1, 2023, all of the debt and hedging arrangements of the Registrants had transitioned to a SOFR-based interest rate based on the terms of the agreements. There were no material impacts from the transition to SOFR and no impacts to any existing accounting conclusions. See Note 14 under "Interest Rate Derivatives" for additional information. Affiliate Transactions The traditional electric operating companies, Southern Power, and Southern Company Gas have agreements with SCS under which certain of the following services are rendered to them at direct or allocated cost: general executive and advisory, general and design engineering, operations, purchasing, accounting, finance, treasury, legal, tax, information technology, marketing, auditing, insurance and pension administration, human resources, systems and procedures, digital wireless communications, cellular tower space, and other services with respect to business and operations, construction management, and Southern Company power pool transactions. These costs are primarily included in other operations and maintenance expenses or capitalized to property, plant, and equipment. Costs for these services from SCS in 2023, 2022, and 2021 were as follows:
| Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 | $ 611 | $ 857 | $ 113 | $ 86 | $ 261
2022 | 549 | 762 | 115 | 86 | 262
2021 | 504 | 663 | 120 | 89 | 239
Alabama Power and Georgia Power also have agreements with Southern Nuclear under which Southern Nuclear renders the following nuclear-related services at cost: general executive and advisory services; general operations, management, and technical services; administrative services including procurement, accounting, employee relations, systems, and procedures services; strategic planning and budgeting services; other services with respect to business and operations; and, for Georgia Power, construction management. These costs are primarily included in other operations and maintenance expenses or capitalized to property, plant, and equipment. Costs for these services in 2023, 2022, and 2021 amounted to $251 million, $267 million, and $258 million, respectively, for Alabama Power and $899 million, $895 million, and $906 million, respectively, for Georgia Power. See Note 2 under "Georgia Power – Nuclear Construction" for additional information regarding Southern Nuclear's construction management of Plant Vogtle Unit 4 for Georgia Power. Cost allocation methodologies used by SCS and Southern Nuclear prior to the repeal of the Public Utility Holding Company Act of 1935, as amended, were approved by the SEC. Subsequently, additional cost allocation methodologies have been reported to the FERC and management believes they are reasonable. The FERC permits services to be rendered at cost by system service companies. Alabama Power's and Georgia Power's power purchases from affiliates through the Southern Company power pool are included in purchased power, affiliates on their respective statements of income. Mississippi Power's and Southern Power's power purchases from affiliates through the Southern Company power pool are included in purchased power on their respective statements of income and were as follows:
| Mississippi Power | Southern Power
| (in millions)
2023 | $ 4 | $ 13
2022 | 4 | 29
2021 | 9 | 15
Georgia Power has entered into several PPAs with Southern Power for capacity and energy. Georgia Power's total expenses associated with these PPAs were $143 million, $151 million, and $132 million in 2023, 2022, and 2021, respectively. Southern Power's total revenues from all PPAs with Georgia Power, included in wholesale revenue affiliates on Southern Power's consolidated statements of income, were $145 million, $154 million, and $139 million for 2023, 2022, and 2021, respectively. Included within these revenues were affiliate PPAs accounted for as operating leases, which totaled $116 million, $116 million, and $112 million for 2023, 2022, and 2021, respectively. See Note 9 for additional information. Also see Note 2 under "Georgia Power – Integrated Resource Plans" for information regarding additional affiliate PPAs commencing in 2024. SCS (as agent for Alabama Power, Georgia Power, and Southern Power) and Southern Company Gas have long-term interstate natural gas transportation agreements with SNG that are governed by the terms and conditions of SNG's natural gas tariff and are subject to FERC regulation. See Note 7 under "Southern Company Gas – Equity Method Investments" for additional information. Transportation costs under these agreements in 2023, 2022, and 2021 were as follows:
| Alabama Power | Georgia Power | Southern Power | Southern Company Gas
| (in millions)
2023 | $ 12 | $ 101 | $ 34 | $ 28
2022 | 18 | 99 | 37 | 27
2021 | 14 | 108 | 31 | 29
SCS, as agent for the traditional electric operating companies and Southern Power, has agreements with certain subsidiaries of Southern Company Gas to purchase natural gas. Natural gas purchases made under these agreements were immaterial for Alabama Power, Georgia Power, and Mississippi Power for all periods presented, immaterial for Southern Power in 2023 and 2022, and $18 million for Southern Power in 2021. Alabama Power and Mississippi Power jointly own Plant Greene County. The companies have an agreement under which Alabama Power operates Plant Greene County and Mississippi Power reimburses Alabama Power for its proportionate share of non-fuel operations and maintenance expenses, which totaled $5 million, $6 million, and $10 million in 2023, 2022, and 2021, respectively. See Note 5 under "Joint Ownership Agreements" for additional information. Alabama Power, Georgia Power, and Mississippi Power each have agreements with PowerSecure for equipment purchases and/or services related to utility infrastructure construction, distributed energy, and energy efficiency projects. Costs under these agreements were immaterial for all periods presented. Southern Company Gas has a $77 million contract with the U.S. General Services Administration to increase energy efficiency at certain federal buildings across Georgia, with completion expected by the end of 2024. Southern Company Gas engaged PowerSecure to provide the majority of the construction services under the contract. During 2023 and 2022, Southern Company Gas paid $29 million and $10 million, respectively, to PowerSecure related to this agreement. See Note 7 under "SEGCO" for information regarding Alabama Power's and Georgia Power's equity method investment in SEGCO and related affiliate purchased power costs, as well as Alabama Power's gas pipeline ownership agreement with SEGCO. Southern Power has several agreements with SCS for transmission services, which are billed to Southern Power based on the Southern Company Open Access Transmission Tariff as filed with the FERC. Transmission services purchased by Southern Power from SCS totaled $33 million, $39 million, and $28 million for 2023, 2022, and 2021, respectively, and were charged to other operations and maintenance expenses in Southern Power's consolidated statements of income. The traditional electric operating companies and Southern Power may jointly enter into various types of wholesale energy, natural gas, and certain other contracts, either directly or through SCS as agent. Each participating company may be jointly and severally liable for the obligations incurred under these agreements. See Note 14 under "Contingent Features" for additional information. Southern Power and the traditional electric operating companies generally settle amounts related to the above transactions on a monthly basis in the month following the performance of such services or the purchase or sale of electricity. See "Revenues – Southern Power" herein for additional information. The traditional electric operating companies, Southern Power, and Southern Company Gas provide incidental services to and receive such services from other Southern Company subsidiaries which are generally minor in duration and amount. Except as described herein, the traditional electric operating companies, Southern Power, and Southern Company Gas neither provided nor received any material services to or from affiliates in any year presented. Regulatory Assets and Liabilities The traditional electric operating companies and the natural gas distribution utilities are subject to accounting requirements for the effects of rate regulation. Regulatory assets represent probable future revenues associated with certain costs that are expected to be recovered from customers through the ratemaking process. Regulatory liabilities represent costs recovered that are expected to be incurred in the future or probable future reductions in revenues associated with amounts that are expected to be credited to customers through the ratemaking process. In the event that a portion of a traditional electric operating company's or a natural gas distribution utility's operations is no longer subject to applicable accounting rules for rate regulation, such company would be required to write off to income or reclassify to AOCI related regulatory assets and liabilities that are not specifically recoverable through regulated rates. In addition, the traditional electric operating company or the natural gas distribution utility would be required to determine if any impairment to other assets, including plant, exists and write down the assets, if impaired, to their fair values. All regulatory assets and liabilities are to be reflected in rates. See Note 2 for additional information including details of regulatory assets and liabilities reflected in the balance sheets for Southern Company, the traditional electric operating companies, and Southern Company Gas. Revenues The Registrants generate revenues from a variety of sources which are accounted for under various revenue accounting guidance, including revenue from contracts with customers, lease, derivative, and regulatory accounting. See Notes 4, 9, and 14 for additional information. Traditional Electric Operating Companies The majority of the revenues of the traditional electric operating companies are generated from contracts with retail electric customers. These revenues, generated from the integrated service to deliver electricity when and if called upon by the customer, are recognized as a single performance obligation satisfied over time, at a tariff rate, and as electricity is delivered to the customer during the month. Unbilled revenues related to retail sales are accrued at the end of each fiscal period. Retail rates may include provisions to adjust revenues for fluctuations in fuel costs, fuel hedging, the energy component of purchased power costs, and certain other costs. Revenues are adjusted for differences between these actual costs and amounts billed in current regulated rates. Under or over recovered regulatory clause revenues are recorded in the balance sheets and are recovered from or returned to customers, respectively, through adjustments to the billing factors. See Note 2 for additional information regarding regulatory matters of the traditional electric operating companies. Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms. Energy and other revenues are generally recognized as services are provided. The contracts for capacity and energy in a wholesale PPA have multiple performance obligations where the contract's total transaction price is allocated to each performance obligation based on the standalone selling price. The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with the performance obligations. Generally, the traditional electric operating companies recognize revenue as the performance obligations are satisfied over time as electricity is delivered to the customer or as generation capacity is available to the customer. For both retail and wholesale revenues, the traditional electric operating companies have elected to recognize revenue for their sales of electricity and capacity using the invoice practical expedient as they generally have a right to consideration in an amount that corresponds directly with the value to the customer of the performance completed to date and that may be invoiced. Payment for goods and services rendered is typically due in the subsequent month following satisfaction of the Registrants' performance obligation. Southern Power Southern Power sells capacity and energy at rates specified under contractual terms in long-term PPAs. These PPAs are accounted for as leases, normal sale derivatives, or contracts with customers. Capacity revenues from PPAs classified as operating leases are recognized on a straight-line basis over the term of the agreement. Energy revenues are recognized in the period the energy is delivered. Capacity revenues from PPAs classified as sales-type leases are recognized by accounting for interest income on the net investment in the lease. Southern Power's non-lease contracts commonly include capacity and energy which are considered separate performance obligations. In these contracts, the total transaction price is allocated to each performance obligation based on the standalone selling price. The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with the performance obligations. Generally, Southern Power recognizes revenue as the performance obligations are satisfied over time, as electricity is delivered to the customer or as generation capacity is made available to the customer. Southern Power generally has a right to consideration in an amount that corresponds directly with the value to the customer of the performance completed to date and may recognize revenue in the amount to which the entity has a right to invoice. Payment for goods and services rendered is typically due in the subsequent month following satisfaction of Southern Power's performance obligation. When multiple contracts exist with the same counterparty, the revenues from each contract are accounted for as separate arrangements. Southern Power may also enter into contracts to sell short-term capacity in the wholesale electricity markets. These sales are generally classified as mark-to-market derivatives and net unrealized gains and losses on such contracts are recorded in wholesale revenues. See Note 14 and "Financial Instruments" herein for additional information. Southern Company Gas Gas Distribution Operations Southern Company Gas records revenues when goods or services are provided to customers. Those revenues are based on rates approved by the state regulatory agencies of the natural gas distribution utilities. Atlanta Gas Light operates in a deregulated natural gas market wher eby M arketers, rather than a traditional utility, sell natural gas to end-use customers in Georgia and handle customer billing functions. As required by the Georgia PSC, Atlanta Gas Light bills Marketers in equal monthly installments for each residential, commercial, and industrial end-use customer's distribution costs as well as for capacity costs utilizing a seasonal rate design for the calculation of each residential end-use customer's annual straight-fixed-variable charge, which reflects the historic volumetric usage pattern for the entire residential class. The majority of the revenues of Southern Company Gas are generated from contracts with natural gas distribution customers. Revenues from this integrated service to deliver gas when and if called upon by the customer are recognized as a single performance obligation satisfied over time and are recognized at a tariff rate as gas is delivered to the customer during the month. The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with the performance obligations. Generally, Southern Company Gas recognizes revenue as the performance obligations are satisfied over time as natural gas is delivered to the customer. The performance obligations related to wholesale gas services are satisfied, and revenue is recognized, at a point in time when natural gas is delivered to the customer. Southern Company Gas has elected to recognize revenue for sales of gas using the invoice practical expedient as it generally has a right to consideration in an amount that corresponds directly with the value to the customer of the performance completed to date and that may be invoiced. Payment for goods and services rendered is typically due in the subsequent month following satisfaction of Southern Company Gas' performance obligation. With the exception of Atlanta Gas Light, the natural gas distribution utilities have rate structures that include volumetric rate designs that allow the opportunity to recover certain costs based on gas usage. Revenues from sales and transportation services are recognized in the same period in which the related volumes are delivered to customers. Revenues from residential and certain commercial and industrial customers are recognized on the basis of scheduled meter readings. Additionally, unbilled revenues are recognized for estimated deliveries of gas not yet billed to these customers, from the last bill date to the end of the accounting period. For other commercial and industrial customers, revenues are based on actual deliveries through the end of the period. *The tariffs for the natural gas distribution utilities include provisions which allow for the recognition of certain revenues prior to the time such revenues are billed to customers. These provisions are referred to as alternative revenue programs and provide for the recognition of certain revenues prior to billing, as long as the amounts recognized will be collected from customers within 24 months of recognition. Revenue related to alternative revenue programs was $20 million, $(5) million, and $11 million in 2023, 2022, and 2021, respectively. These programs are as follows: *Weather normalization adjustments – reduce customer bills when winter weather is colder than normal and increase customer bills when weather is warmer than normal and are included in the tariffs for Virginia Natural Gas and Chattanooga Gas; *Revenue normalization mechanisms – mitigate the impact of conservation and declining customer usage and are contained in the tariffs for Virginia Natural Gas and Nicor Gas; and *Revenue true-up adjustment – included within the provisions of the GRAM program in which Atlanta Gas Light participates as a short-term alternative to formal rate case filings, the revenue true-up feature provides for a positive (or negative) adjustment to record revenue in the amount of any variance to budgeted revenues, which are submitted and approved annually as a requirement of GRAM. Such adjustments are reflected in customer billings in a subsequent program year. *Wholesale Gas Services *Prior to the sale of Sequent on July 1, 2021, Southern Company Gas netted revenues from energy and risk management activities with the associated costs. Profits from sales between segments were eliminated and recognized as goods or services sold to end-use customers. Southern Company Gas recorded wholesale gas services' transactions that qualified as derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses on derivatives held for energy trading purposes were presented on a net basis in revenue. See Note 15 under "Southern Company Gas" for additional information on the sale of Sequent. Gas Marketing Services Southern Company Gas recognizes revenues from natural gas sales and transportation services in the same period in which the related volumes are delivered to customers and recognizes sales revenues from residential and certain commercial and industrial customers on the basis of scheduled meter readings. Southern Company Gas also recognizes unbilled revenues for estimated deliveries of gas not yet billed to these customers from the most recent meter reading date to the end of the accounting period. For other commercial and industrial customers and for all wholesale customers, revenues are based on actual deliveries during the period. Southern Company Gas recognizes revenues on 12-month utility-bill management contracts as the lesser of cumulative earned or cumulative billed amounts. Concentration of Revenue Southern Company, Alabama Power, Georgia Power, Mississippi Power (with the exception of its full requirements cost-based MRA electric tariffs described below), Southern Power, and Southern Company Gas each have a diversified base of customers and no single customer comprises 10% or more of each company's revenues. Mississippi Power provides service under long-term contracts with rural electric cooperative associations and a municipality located in southeastern Mississippi under requirements cost-based MRA electric tariffs, which are subject to regulation by the FERC. The contracts with these wholesale customers represented 14.0% of Mississippi Power's total operating revenues in 2023. Fuel Costs Fuel costs for the traditional electric operating companies and Southern Power are expensed as the fuel is used. Fuel expense generally includes fuel transportation costs and the cost of purchased emissions allowances as they are used. For Alabama Power and Georgia Power, fuel expense also includes the amortization of the cost of nuclear fuel. For the traditional electric operating companies, fuel costs also include gains and/or losses from fuel-hedging programs as approved by their respective state PSCs. Cost of Natural Gas Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, Southern Company Gas charges its utility customers for natural gas consumed using natural gas cost recovery mechanisms set by the applicable state regulatory agencies. Under these mechanisms, all prudently-incurred natural gas costs are passed through to customers without markup, subject to regulatory review. Southern Company Gas defers or accrues the difference between the actual cost of natural gas and the amount of commodity revenue earned in a given period such that no operating income is recognized related to these costs. The deferred or accrued amount is either billed or refunded to customers prospectively through adjustments to the commodity rate. Deferred and accrued natural gas costs are included in the balance sheets as regulatory assets and regulatory liabilities, respectively. Southern Company Gas' gas marketing services' customers are charged for actual or estimated natural gas consumed. Within cost of natural gas, Southern Company Gas also includes costs of lost and unaccounted for gas and gains and losses associated with certain derivatives. Income Taxes The Registrants use the liability method of accounting for deferred income taxes and provide deferred income taxes for all significant income tax temporary differences. In accordance with regulatory requirements, deferred federal ITCs for the traditional electric operating companies are amortized over the average life of the related property, with such amortization normally applied as a credit to reduce depreciation and amortization in the statements of income. Southern Power's and the natural gas distribution utilities' deferred federal ITCs, as well as certain state ITCs for Nicor Gas, are amortized to income tax expense over the life of the respective asset. Under current tax law, certain projects at Southern Power related to the construction of renewable facilities are eligible for federal ITCs. Southern Power estimates eligible costs which, as they relate to acquisitions, may not be finalized until the allocation of the purchase price to assets has been finalized. Southern Power applies the deferred method to ITCs, whereby the ITCs are recorded as a deferred credit and amortized to income tax expense over the life of the respective asset. Furthermore, the tax basis of the asset is reduced by 50% of the ITCs received, resulting in a net deferred tax asset. Southern Power has elected to recognize the tax benefit of this basis difference as a reduction to income tax expense in the year in which the plant reaches commercial operation. State ITCs are recognized as an income tax benefit in the period in which the credits are generated. In addition, certain projects are eligible for federal and state PTCs, which are recognized as an income tax benefit based on KWH production. Federal ITCs and PTCs, as well as state ITCs and other state tax credits available to reduce income taxes payable, were not fully utilized in 2023 and will be carried forward and utilized in future years. In addition, Southern Company is expected to have various state net operating loss (NOL) carryforwards for certain of its subsidiaries, including Mississippi Power and Southern Power, which would result in income tax benefits in the future, if utilized. See Note 10 under "Current and Deferred Income Taxes – Tax Credit Carryforwards" and " – Net Operating Loss Carryforwards" for additional information. In June 2023, the IRS issued temporary regulations related to the transferability of certain tax credits under the IRA. Southern Company and certain subsidiaries have tax credits that are eligible to be transferred. The discount recorded on transferred credits is booked through income tax expense. Under current tax law, Georgia Power is eligible to generate advanced nuclear PTCs for Plant Vogtle Unit 3, which are recognized as an income tax benefit based on KWH production and are eligible to be transferred. Pursuant to the Global Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 under "Georgia Power – Nuclear Construction – Joint Owner Contracts"), Georgia Power is purchasing advanced nuclear PTCs for Plant Vogtle Unit 3 from the other Vogtle Owners. The gain recognized on the purchase of the joint owner PTCs is recognized as an income tax benefit. The Registrants recognize tax positions that are "more likely than not" of being sustained upon examination by the appropriate taxing authorities. See Note 10 under "Unrecognized Tax Benefits" for additional information. Other Taxes Taxes imposed on and collected from customers on behalf of governmental agencies are presented net on the Registrants' statements of income and are excluded from the transaction price in determining the revenue related to contracts with a customer. Southern Company Gas is taxed on its gas revenues by various governmental authorities, but is allowed to recover these taxes from its customers. Revenue taxes imposed on the natural gas distribution utilities are recorded at the amount charged to customers, which may include a small administrative fee, as operating revenues, and the related taxes imposed on Southern Company Gas are recorded as operating expenses on the statements of income. Revenue taxes included in operating expenses were $129 million, $158 million, and $119 million in 2023, 2022, and 2021, respectively. Allowance for Funds Used During Construction and Interest Capitalized The traditional electric operating companies and the natural gas distribution utilities record AFUDC, which represents the estimated debt and equity costs of capital funds that are necessary to finance the construction of new regulated facilities. While cash is not realized currently, AFUDC increases the revenue requirement and is recovered over the service life of the asset through a higher rate base and higher depreciation. The equity component of AFUDC is not taxable. Interest related to financing the construction of new facilities at Southern Power and new facilities not included in the traditional electric operating companies' and Southern Company Gas' regulated rates is capitalized in accordance with standard interest capitalization requirements. Total AFUDC and interest capitalized for the applicable Registrants in 2023, 2022, and 2021 was as follows:
| Southern Company | Alabama Power | Georgia Power(*) | Southern Power | Southern Company Gas
| (in millions)
2023 | $ 400 | $ 109 | $ 251 | $ 3 | $ 37
2022 | 327 | 90 | 213 | — | 24
2021 | 282 | 68 | 190 | 6 | 18
*See Note 2 under "Georgia Power – Nuclear Construction" for information on the inclusion of a portion of construction costs related to Plant Vogtle Unit 4 in Georgia Power's rate base. The average AFUDC composite rates for 2023, 2022, and 2021 for the traditional electric operating companies and the natural gas distribution utilities were as follows:
| 2023 | 2022 | 2021
Alabama Power | 8.1 % | 7.9 % | 7.9 %
Georgia Power(a) | 7.6 % | 7.3 % | 7.2 %
Mississippi Power(b) | — % | 5.3 % | 2.5 %
Southern Company Gas: |  |  |
Atlanta Gas Light | 7.4 % | 7.6 % | 7.7 %
Chattanooga Gas | 7.1 % | 7.1 % | 7.1 %
Nicor Gas | 4.6 % | 2.0 % | 0.1 %
(a)Excludes AFUDC related to the construction of Plant Vogtle Units 3 and 4. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. (b)Mississippi Power's AFUDC was immaterial in 2023. Impairment of Long-Lived Assets The Registrants evaluate long-lived assets and finite-lived intangible assets for impairment when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. The determination of whether an impairment has occurred is based on either a specific regulatory disallowance, a sales transaction price that is less than the asset group's carrying amount, or an estimate of undiscounted future cash flows attributable to the asset group, as compared with the carrying amount of the assets. If an impairment has occurred, the amount of the impairment loss recognized is determined by either the amount of regulatory disallowance or by the amount the carrying amount exceeds the estimated fair value of the assets. For assets identified as held for sale, the carrying amount is compared to the estimated fair value less the cost to sell in order to determine if an impairment loss is required. Until the assets are disposed of, their estimated fair value is re-evaluated when circumstances or events change. See Notes 7 and 9 under "Southern Company Gas" and "Southern Company Leveraged Lease," respectively, and Note 15 under "Southern Company" and "Southern Company Gas" for information regarding impairment charges recorded during the periods presented. Goodwill and Other Intangible Assets Southern Power's intangible assets consist primarily of certain PPAs acquired, which are amortized over the term of the respective PPA. Southern Company Gas' goodwill and other intangible assets primarily relate to its 2016 acquisition by Southern Company. In addition to these items, Southern Company's goodwill and other intangible assets also relate to its 2016 acquisition of PowerSecure. For its 2023 and 2022 annual impairment tests, Southern Company Gas management performed the qualitative assessment and determined that it was more likely than not that the fair value of all of its reporting units with goodwill exceeded their carrying amounts, and therefore no quantitative assessment was required. For its 2021 annual impairment test, Southern Company Gas management performed the quantitative assessment and confirmed that the fair values of all of its reporting units with goodwill exceeded their carrying amounts. For its 2023 and 2021 annual impairment tests, PowerSecure management performed the quantitative assessment, which resulted in the fair value of PowerSecure exceeding its carrying amount. For its 2022 annual impairment test, PowerSecure management performed the quantitative assessment, which resulted in the fair value of PowerSecure being lower than its carrying amount. The fair value was estimated using a discounted cash flow analysis. The decline in fair value primarily resulted from declining macroeconomic conditions, reducing sales growth and estimated cash flows. As a result, a goodwill impairment of $119 million was recorded in the fourth quarter 2022. At December 31, 2023 and 2022, goodwill was as follows:
| At December 31, 2023 | At December 31, 2022
| (in millions)
Southern Company | $ 5,161 | $ 5,161
Southern Company Gas: |  |
Gas distribution operations | $ 4,034 | $ 4,034
Gas marketing services | 981 | 981
Southern Company Gas total | $ 5,015 | $ 5,015
At December 31, 2023 and 2022, other intangible assets were as follows:
| At December 31, 2023 |  | At December 31, 2022
| Gross Carrying Amount | Accumulated Amortization | Other Intangible Assets, Net |  | Gross Carrying Amount | Accumulated Amortization | Other Intangible Assets, Net
| (in millions) |  | (in millions)
Southern Company |  |  |  |  |  |  |
Subject to amortization: |  |  |  |  |  |  |
Customer relationships | $ 212 | $ (172) | $ 40 |  | $ 212 | $ (162) | $ 50
Trade names | 64 | (53) | 11 |  | 64 | (44) | 20
PPA fair value adjustments | 390 | (148) | 242 |  | 390 | (129) | 261
Other | 3 | (3) | — |  | 5 | (5) | —
Total subject to amortization | $ 669 | $ (376) | $ 293 |  | $ 671 | $ (340) | $ 331
Not subject to amortization: |  |  |  |  |  |  |
FCC licenses | 75 | — | 75 |  | 75 | — | 75
Total other intangible assets | $ 744 | $ (376) | $ 368 |  | $ 746 | $ (340) | $ 406
Southern Power(*) |  |  |  |  |  |  |
PPA fair value adjustments | $ 390 | $ (148) | $ 242 |  | $ 390 | $ (129) | $ 261
Southern Company Gas(*) |  |  |  |  |  |  |
Gas marketing services |  |  |  |  |  |  |
Customer relationships | $ 156 | $ (145) | $ 11 |  | $ 156 | $ (139) | $ 17
Trade names | 26 | (21) | 5 |  | 26 | (17) | 9
Total other intangible assets | $ 182 | $ (166) | $ 16 |  | $ 182 | $ (156) | $ 26
*All subject to amortization. Amortization associated with other intangible assets in 2023, 2022, and 2021 was as follows:
| 2023 | 2022 | 2021
| (in millions)
Southern Company(a) | $ 38 | $ 39 | $ 44
Southern Power(b) | 20 | 20 | 20
Southern Company Gas: |  |  |
Gas marketing services | 10 | 11 | 15
(a)Includes $20 million annually recorded as a reduction to operating revenues. (b)Recorded as a reduction to operating revenues. At December 31, 2023, the estimated amortization associated with other intangible assets for the next five years is as follows:
| 2024 | 2025 | 2026 | 2027 | 2028
| (in millions)
Southern Company | $ 35 | $ 32 | $ 27 | $ 24 | $ 24
Southern Power | 20 | 20 | 20 | 20 | 20
Southern Company Gas | 7 | 6 | 3 | — | —
Acquisition Accounting At the time of an acquisition, management will assess whether acquired assets and activities meet the definition of a business. Acquisitions that meet the definition of a business are accounted for under the acquisition method, and operating results from the date of acquisition are included in the acquiring entity's financial statements. Identifiable assets acquired, liabilities assumed, and any noncontrolling interests (including any intangible assets) are recognized and measured at fair value. Assets acquired that do not meet the definition of a business are accounted for as an asset acquisition. The purchase price of each asset acquisition is allocated based on the relative fair value of assets acquired. Determining the fair value of assets acquired and liabilities assumed requires management judgment and management may engage independent valuation experts to assist in this process. Fair values are determined by using market participant assumptions and typically include the timing and amounts of future cash flows, incurred construction costs, the nature of acquired contracts, discount rates, power market prices, and expected asset lives. For potential or successful acquisitions that meet the definition of a business, any due diligence or transaction costs incurred are expensed as incurred. If the acquisition is an asset acquisition, direct and incremental transaction costs can be capitalized as a component of the cost of the assets acquired. Historically, any contingent consideration relates to fixed amounts due to the seller once an acquired construction project is placed in service. For contingent consideration with variable payments, management fair values the arrangement with any changes recorded in the statements of income. See Note 13 for additional fair value information. Development Costs For Southern Power, development costs are capitalized once a project is probable of completion, primarily based on a review of its economics and operational feasibility, as well as the status of power off-take agreements and regulatory approvals, if applicable. Southern Power's capitalized development costs are included in CWIP on the balance sheets. All of Southern Power's development costs incurred prior to the determination that a project is probable of completion are expensed as incurred and included in other operations and maintenance expense in the statements of income. If it is determined that a project is no longer probable of completion, any of Southern Power's capitalized development costs are expensed and included in other operations and maintenance expense in the statements of income. Long-Term Service Agreements The traditional electric operating companies and Southern Power have entered into LTSAs for the purpose of securing maintenance support for certain of their generating facilities. The LTSAs cover all planned inspections on the covered equipment, which generally includes the cost of all labor and materials. The LTSAs also obligate the counterparties to cover the costs of unplanned maintenance on the covered equipment subject to limits and scope specified in each contract. Payments made under the LTSAs for the performance of any planned inspections or unplanned capital maintenance are recorded in the statements of cash flows as investing activities. Receipts of major parts into materials and supplies inventory prior to planned inspections are treated as noncash transactions in the statements of cash flows. Any payments made prior to the work being performed are recorded as prepayments in other current assets and noncurrent assets on the balance sheets. At the time work is performed, an appropriate amount is accrued for future payments or transferred from the prepayment and recorded as property, plant, and equipment or expensed. Transmission Receivables/Prepayments As a result of Southern Power's acquisition and construction of generating facilities, Southern Power has transmission receivables and/or prepayments representing the portion of interconnection network and transmission upgrades that will be reimbursed to Southern Power. Upon completion of the related project, transmission costs are generally reimbursed by the interconnection provider within a five-year period and the receivable/prepayments are reduced as payments or services are received. Cash, Cash Equivalents, and Restricted Cash For purposes of the financial statements, temporary cash investments are considered cash equivalents. Temporary cash investments are securities with original maturities of 90 days or less. The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets that total to the amount shown in the statements of cash flows for the applicable Registrants:
| Southern Company | Alabama Power | Georgia Power | Southern Power | Southern Company Gas
| (in millions)
At December 31, 2023 |  |  |  |  |
Cash and cash equivalents | $ 748 | $ 324 | $ 9 | $ 124 | $ 33
Restricted cash(a): |  |  |  |  |
Other current assets | 141 | 85 | 37 | 17 | 2
Other deferred charges and assets | 31 | — | 29 | 3 | —
Total cash, cash equivalents, and restricted cash(b) | $ 921 | $ 409 | $ 75 | $ 144 | $ 35
At December 31, 2022 |  |  |  |  |
Cash and cash equivalents | $ 1,917 | $ 687 | $ 364 | $ 131 | $ 81
Restricted cash(a): |  |  |  |  |
Other current assets | 62 | — | 60 | — | 2
Other deferred charges and assets | 58 | — | 56 | 3 | —
Total cash, cash equivalents, and restricted cash(b) | $ 2,037 | $ 687 | $ 480 | $ 133 | $ 83
(a)For Alabama Power, reflects proceeds from the issuance of solid waste disposal facility revenue bonds in 2023. For Georgia Power, reflects proceeds from the issuance of solid waste disposal facility revenue bonds in 2022. See Note 8 under "Long-term Debt" for additional information. For Southern Power, reflects $17 million at December 31, 2023 resulting from an arbitration award held to fund future replacement costs and $3 million at both December 31, 2023 and 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. See Note 3 under "General Litigation Matters – Southern Power" and Note 15 under "Southern Power" for additional information. For Southern Company Gas, reflects collateral for workers' compensation, life insurance, and long-term disability insurance. (b)Total may not add due to rounding. Storm Damage and Reliability Reserves In accordance with their respective state PSC orders, the traditional electric operating companies accrue certain amounts annually related to storm damage recovery. Each traditional electric operating company maintains a reserve to cover or is allowed to defer and recover the cost of damages from major storms to its transmission and distribution lines and, for Mississippi Power, the cost of uninsured damages to its generation facilities and other property. Alabama Power also has authority from the Alabama PSC to accrue certain additional amounts as circumstances warrant. Alabama Power recorded an additional accrual of $65 million in 2021. Storm damage reserve activity for the traditional electric operating companies during 2023 was as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power
| (in millions)
Balance at December 31, 2022 | $ 216 | $ 97 | $ 83 | $ 36
Accrual | 61 | 18 | 31 | 12
Weather-related damages | (211) | (39) | (168) | (4)
Balance at December 31, 2023 | $ 66 | $ 76 | $ (54) | $ 44
The traditional electric operating companies accrued the following amounts related to storm damage recovery in 2022 and 2021:
| Southern Company(a)(b) | Alabama Power(a) | Georgia Power | Mississippi Power(b)
| (in millions)
2022 | $ 239 | $ 19 | $ 213 | $ 7
2021 | 286 | 75 | 213 | (2)
(a)Alabama Power's 2021 amount includes the $65 million additional accrual discussed above. (b)Mississippi Power's net accrual includes carrying costs, as well as amortization of related excess deferred income tax benefits. In 2022, costs for weather-related damages charged against storm damage reserves totaled $24 million and $82 million for Alabama Power and Georgia Power, respectively, and were immaterial for Mississippi Power. See Note 2 under "Alabama Power – Rate NDR," "Georgia Power – Storm Damage Recovery," and "Mississippi Power – System Restoration Rider" for additional information regarding each company's storm damage reserve. During 2022, the Alabama PSC and the Mississippi PSC authorized Alabama Power and Mississippi Power, respectively, to make accruals to a reliability reserve if certain conditions are met. During 2023 and 2022, Alabama Power and Mississippi Power accrued the following amounts to their reliability reserves:
| Southern Company | Alabama Power | Mississippi Power
| (in millions)
2023 | $ 63 | $ 52 | $ 11
2022 | 191 | 166 | 25
See Note 2 under "Alabama Power – Reliability Reserve Accounting Order" and "Mississippi Power – Reliability Reserve Accounting Order" for additional information. Materials and Supplies Materials and supplies for the traditional electric operating companies generally includes the average cost of transmission, distribution, and generating plant materials. Materials and supplies for Southern Company Gas generally includes propane gas inventory, liquefied natural gas inventory, fleet fuel, and other materials and supplies. Materials and supplies for Southern Power generally includes the average cost of generating plant materials. Materials are recorded to inventory when purchased and then expensed or capitalized to property, plant, and equipment, as appropriate, at weighted average cost when installed. In addition, certain major parts are recorded as inventory when acquired and then capitalized at cost when installed to property, plant, and equipment. Fuel Inventory Fuel inventory for the traditional electric operating companies includes the average cost of coal, natural gas, oil, transportation, and emissions allowances. Fuel inventory for Southern Power, which is included in other current assets, includes the average cost of oil, natural gas, and emissions allowances. Fuel is recorded to inventory when purchased and then expensed, at weighted average cost, as used. Emissions allowances granted by the EPA are included in inventory at zero cost. The traditional electric operating companies recover fuel expense through fuel cost recovery rates approved by each state PSC or, for wholesale rates, the FERC. Natural Gas for Sale With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a weighted average cost of gas basis. In Georgia's deregulated, competitive environment, Marketers sell natural gas to firm end-use customers at market-based prices. On a monthly basis, Atlanta Gas Light assigns to Marketers the majority of the pipeline storage services that it has under contract, along with a corresponding amount of inventory. Atlanta Gas Light retains and manages a portion of its pipeline storage assets and related natural gas inventories for system balancing and to serve system demand. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year-end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year-end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated. The cost of natural gas, including inventory costs, is recovered from customers under a purchased gas recovery mechanism adjusted for differences between actual costs and amounts billed; therefore, LIFO liquidations have no impact on Southern Company's or Southern Company Gas' net income. At December 31, 2023, the Nicor Gas LIFO inventory balance w as $186 million. Based on the average cost of gas purchased in December 2023, the estimated replacement cost of Nicor Gas' inventory at December 31, 2023 was $268 million. Provision for Uncollectible Accounts The customers of the traditional electric operating companies and the natural gas distribution utilities are billed monthly. For the majority of receivables, a provision for uncollectible accounts is established based on historical collection experience and other factors. For the remaining receivables, if the company is aware of a specific customer's inability to pay, a provision for uncollectible accounts is recorded to reduce the receivable balance to the amount reasonably expected to be collected. If circumstances change, the estimate of the recoverability of accounts receivable could change as well. Circumstances that could affect this estimate include, but are not limited to, customer credit issues, customer deposits, and general economic conditions. Customers' accounts are written off once they are deemed to be uncollectible. For all periods presented, uncollectible accounts averaged less than 1% of revenues for each Registrant. Credit risk exposure at Nicor Gas is mitigated by a bad debt rider approved by the Illinois Commission. The bad debt rider provides for the recovery from (or refund to) customers of the difference between Nicor Gas' actual bad debt experience on an annual basis and the benchmark bad debt expense used to establish its base rates for the respective year. Concentration of Credit Risk Concentration of credit risk occurs at Atlanta Gas Light for amounts billed for services and other costs to its customers, which consist of 13 Marketers in Georgia (including SouthStar). The credit risk exposure to the Marketers varies seasonally, with the lowest exposure in the non-peak summer months and the highest exposure in the peak winter months. Marketers are responsible for the retail sale of natural gas to end-use customers in Georgia. The functions of the retail sale of gas include the purchase and sale of natural gas, customer service, billings, and collections. The provisions of Atlanta Gas Light's tariff allow Atlanta Gas Light to obtain credit security support in an amount equal to a minimum of two times a Marketer's highest month's estimated bill from Atlanta Gas Light. Financial Instruments The traditional electric operating companies and Southern Power use derivative financial instruments to limit exposure to fluctuations in interest rates, the prices of certain fuel purchases, electricity purchases and sales, and occasionally foreign currency exchange rates. Southern Company Gas uses derivative financial instruments to limit exposure to fluctuations in natural gas prices, weather, interest rates, and commodity prices. All derivative financial instruments are recognized as either assets or liabilities on the balance sheets (included in "Other" or shown separately as "Risk Management Activities") and are measured at fair value. See Note 13 for additional information regarding fair value. Substantially all of the traditional electric operating companies' and Southern Power's bulk energy purchases and sales contracts that meet the definition of a derivative are excluded from fair value accounting requirements because they qualify for the "normal" scope exception, and are accounted for under the accrual method. Derivative contracts that qualify as cash flow hedges of anticipated transactions or are recoverable through the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs result in the deferral of related gains and losses in AOCI or regulatory assets and liabilities, respectively, until the hedged transactions occur. Other derivative contracts that qualify as fair value hedges are marked to market through current period income and are recorded on a net basis in the statements of income. Cash flows from derivatives are classified on the statements of cash flows in the same category as the hedged item. See Note 14 for additional information regarding derivatives. The Registrants offset fair value amounts recognized for multiple derivative instruments executed with the same counterparty under netting arrangements. The Registrants had no outstanding collateral repayment obligations or rights to reclaim collateral arising from derivative instruments recognized at December 31, 2023. The Registrants are exposed to potential losses related to financial instruments in the event of counterparties' nonperformance. The Registrants have established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk. Southern Company Gas Southern Company Gas enters into weather derivative contracts as economic hedges of natural gas revenues in the event of warmer-than-normal weather in the Heating Season. Exchange-traded options are carried at fair value, with changes reflected in natural gas revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are also reflected in natural gas revenues in the statements of income. Southern Company Gas enters into transactions to secure transportation capacity between delivery points in order to serve its customers and various markets. NYMEX futures and OTC contracts are used to capture the price differential or spread between the locations served by the capacity to substantially protect the natural gas revenues that will ultimately be realized when the physical flow of natural gas between delivery points occurs. These contracts generally meet the definition of derivatives and are carried at fair value on the balance sheets, with changes in fair value included in earnings in the period of change. These contracts are not designated as hedges for accounting purposes. The purchase, transportation, storage, and sale of natural gas are accounted for on a weighted average cost or accrual basis, as appropriate, rather than on the fair value basis utilized for the derivatives used to mitigate the natural gas price risk associated with the storage and transportation portfolio. Monthly demand charges are incurred for the contracted storage and transportation capacity and payments associated with asset management agreements, and these demand charges and payments are recognized on the statements of income in the period they are incurred. This difference in accounting methods can result in volatility in reported earnings, even though the economic margin is substantially unchanged from the dates the transactions were consummated. Comprehensive Income The objective of comprehensive income is to report a measure of all changes in common stock equity of an enterprise that result from transactions and other economic events of the period other than transactions with owners. Comprehensive income consists of net income attributable to the Registrant, changes in the fair value of qualifying cash flow hedges, and reclassifications for amounts included in net income. Comprehensive income also consists of certain changes in pension and other postretirement benefit plans for Southern Company, Southern Power, and Southern Company Gas. AOCI (loss) balances, net of tax effects, for Southern Company, Southern Power, and Southern Company Gas were as follows:
| Qualifying Hedges |  | Pension and Other Postretirement Benefit Plans |  | Accumulated Other Comprehensive Income (Loss)(*)
| (in millions)
Southern Company |  |  |  |  |
Balance at December 31, 2022 | $ (149) |  | $ (18) |  | $ (167)
Current period change | 28 |  | (38) |  | (10)
Balance at December 31, 2023 | $ (121) |  | $ (56) |  | $ (177)
Southern Power |  |  |  |  |
Balance at December 31, 2022 | $ (9) |  | $ (9) |  | $ (18)
Current period change | 8 |  | (7) |  | 1
Balance at December 31, 2023 | $ (1) |  | $ (16) |  | $ (17)
Southern Company Gas |  |  |  |  |
Balance at December 31, 2022 | $ (25) |  | $ 56 |  | $ 31
Current period change | 1 |  | (16) |  | (15)
Balance at December 31, 2023 | $ (24) |  | $ 40 |  | $ 16
*May not add due to rounding. Variable Interest Entities The Registrants may hold ownership interests in a number of business ventures with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE. The primary beneficiary of a VIE is required to consolidate the VIE when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. See Note 7 for additional information regarding VIEs. 2. REGULATORY MATTERS Regulatory Assets and Liabilities Details of regulatory assets and (liabilities) reflected in the balance sheets at December 31, 2023 and 2022 are provided in the following tables:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
At December 31, 2023 |  |  |  |  |
AROs(a)(w) | $ 5,733 | $ 1,936 | $ 3,505 | $ 247 | $ —
Retiree benefit plans(b)(w) | 3,011 | 815 | 976 | 140 | 146
Remaining net book value of retired assets(c) | 1,357 | 499 | 841 | 17 | —
Deferred income tax charges(d) | 897 | 262 | 605 | 28 | —
Under recovered regulatory clause revenues(e) | 413 | 381 | — | 12 | 20
Fuel-hedging (realized and unrealized) losses(f) | 270 | 100 | 121 | 49 | —
Deferred depreciation(g) | 270 | 143 | 127 | — | —
Environmental remediation(h)(w) | 255 | — | 20 | — | 235
Loss on reacquired debt(i) | 238 | 35 | 197 | 5 | 1
Vacation pay(j)(w) | 217 | 83 | 107 | 11 | 16
Software and cloud computing costs(k) | 150 | 59 | 84 | 2 | 5
Regulatory clauses(l) | 140 | 112 | — | — | 28
Storm damage(m) | 92 | — | 54 | 38 | —
Nuclear outage(n) | 83 | 50 | 33 | — | —
Long-term debt fair value adjustment(o) | 60 | — | — | — | 60
Qualifying repairs of natural gas distribution systems(p) | 40 | — | — | — | 40
Plant Daniel Units 3 and 4(q) | 25 | — | — | 25 | —
Kemper County energy facility assets, net(r) | 7 | — | — | 7 | —
Other regulatory assets(s) | 182 | 39 | 33 | 18 | 93
Deferred income tax credits(d) | (4,686) | (1,506) | (2,161) | (241) | (759)
Other cost of removal obligations(a) | (1,312) | 28 | 617 | (186) | (1,771)
Over recovered regulatory clause revenues(e) | (287) | (3) | (46) | — | (238)
Reliability reserves(t) | (179) | (143) | — | (36) | —
Storm/property damage reserves(t) | (120) | (76) | — | (44) | —
Customer refunds(u) | (19) | (15) | (4) | — | —
Fuel-hedging (realized and unrealized) gains(f) | (6) | (5) | (1) |  | —
Other regulatory liabilities(v) | (308) | (74) | (18) | (2) | (101)
Total regulatory assets (liabilities), net | $ 6,523 | $ 2,720 | $ 5,090 | $ 90 | $ (2,225)
At December 31, 2022 |  |  |  |  |
AROs(a)(w) | $ 6,096 | $ 1,971 | $ 3,829 | $ 242 | $ —
Retiree benefit plans(b)(w) | 2,517 | 675 | 848 | 113 | 114
Remaining net book value of retired assets(c) | 1,543 | 562 | 962 | 19 | —
Under recovered regulatory clause revenues(e) | 953 | 788 | — | 31 | 134
Deferred income tax charges(d) | 866 | 250 | 583 | 30 | —
Environmental remediation(h)(w) | 294 | — | 25 | — | 269
Loss on reacquired debt(i) | 257 | 38 | 213 | 5 | 1
Vacation pay(j)(w) | 212 | 82 | 108 | 10 | 12
Regulatory clauses(l) | 142 | 142 | — | — | —
Software and cloud computing costs(k) | 111 | 46 | 59 | — | 6
Nuclear outage(n) | 82 | 52 | 30 | — | —
Long-term debt fair value adjustment(o) | 69 | — | — | — | 69
Fuel-hedging (realized and unrealized) losses(f) | 60 | 15 | 45 | — | —
Storm damage(m) | 44 | — | — | 44 | —
Plant Daniel Units 3 and 4(q) | 27 | — | — | 27 | —
Qualifying repairs of natural gas distribution systems(p) | 26 | — | — | — | 26
Kemper County energy facility assets, net(r) | 20 | — | — | 20 | —
Other regulatory assets(s) | 171 | 36 | 27 | 16 | 92
Deferred income tax credits(d) | (5,251) | (1,925) | (2,244) | (269) | (788)
Other cost of removal obligations(a) | (1,430) | 11 | 462 | (196) | (1,707)
Storm/property damage reserves(t) | (216) | (97) | (83) | (36) | —
Reliability reserves(t) | (191) | (166) | — | (25) | —
Customer refunds(u) | (183) | (62) | (121) | — | —
Fuel-hedging (realized and unrealized) gains(f) | (83) | (38) | (21) | (24) | —
Over recovered regulatory clause revenues(e) | (64) | — | (38) | — | (26)
Other regulatory liabilities(v) | (239) | (40) | (21) | (3) | (93)
Total regulatory assets (liabilities), net | $ 5,833 | $ 2,340 | $ 4,663 | $ 4 | $ (1,891)
Unless otherwise noted, the following recovery and amortization periods for these regulatory assets and (liabilities) have been approved by the respective state PSC or regulatory agency: (a)AROs and other cost of removal obligations generally are recorded over the related property lives, which may range up to 64 years for Alabama Power, 56 years for Georgia Power, 55 years for Mississippi Power, and 85 years for Southern Company Gas. AROs and cost of removal obligations are settled and trued up following completion of the related activities. Alabama Power is recovering CCR ARO expenditures over a 38-year period ending in 2054 through Rate CNP Compliance. Effective January 1, 2023, Georgia Power is recovering CCR ARO expenditures over four-year periods through its ECCR tariff. Prior to 2023, expenditures were recovered over three-year periods. See "Georgia Power – Rate Plans" herein and Note 6 for additional information. (b)Recovered and amortized over the average remaining service period, which may range up to 13 years for Alabama Power and Mississippi Power and up to 14 years for Georgia Power and Southern Company Gas. Southern Company's balances also include amounts at SCS and Southern Nuclear that are allocated to the applicable regulated utilities. See Note 11 for additional information. (c)Alabama Power: Primarily represents the net book value of Plant Gorgas Unit 10 ($451 million at December 31, 2023) being amortized over 14 years (through 2037) and Plant Barry Unit 4 ($39 million at December 31, 2023) being amortized over 11 years (through 2034). See "Alabama Power – Environmental Accounting Order" herein for additional information. Georgia Power: Net book values of Plant Wansley Units 1 and 2, Plant Hammond Units 1 through 4, and Plant Branch Unit 4 (totaling $488 million, $339 million, and $8 million, respectively, at December 31, 2023) are being amortized over remaining periods between one and 12 years (between 2024 and 2035). Balance also includes unusable materials and supplies inventories, for which the Georgia PSC will determine a recovery period in a future base rate case. Mississippi Power: Represents net book value of certain environmental compliance assets at Plant Watson and Plant Greene County. The retail portion is being amortized over a 10-year period through 2030 and the wholesale portion is being amortized over a 14-year period through 2035. See "Mississippi Power – Environmental Compliance Overview Plan" herein for additional information. (d)Deferred income tax charges are recovered and deferred income tax credits are primarily amortized over the related property lives, which may range up to 64 years for Alabama Power, 56 years for Georgia Power, 55 years for Mississippi Power, and 85 years for Southern Company Gas. See Note 10 for additional information. As a result of the Tax Reform Legislation, these accounts include certain deferred income tax assets and liabilities not subject to normalization, as described further below: Alabama Power: Related amounts at December 31, 2023 include excess federal deferred income tax liabilities that are available for the benefit of customers in 2024 and/or 2025, as discussed under "Alabama Power – Excess Accumulated Deferred Income Tax Accounting Order" herein. Remaining amounts are being recovered and amortized ratably over the related property lives. Georgia Power: Related amounts include $145 million of deferred income tax assets related to construction costs for Plant Vogtle Units 3 and 4 to be recovered over a 10-year period beginning the month after Unit 4 achieves commercial operation. See "Georgia Power – Nuclear Construction – Regulatory Matters" herein for additional information on recovery of costs related to Plant Vogtle Units 3 and 4. Mississippi Power: Related amounts include retail deferred income tax liabilities ($11 million at December 31, 2023) that are expected to be fully amortized through 2024. Southern Company Gas: Related amounts include deferred income tax liabilities ($1 million at December 31, 2023) being amortized through 2024. See "Southern Company Gas – Rate Proceedings" herein for additional information. (e)Alabama Power: Balances are recorded monthly and expected to be recovered over periods of up to seven years, with the majority expected to be recovered within one year. See "Alabama Power – Rate CNP PPA," " – Rate CNP Compliance," and " – Rate ECR" herein for additional information. Georgia Power: Balances are recorded monthly and expected to be recovered or returned within two years. See "Georgia Power – Rate Plans" herein for additional information. Mississippi Power: At December 31, 2023, $12 million is expected to be recovered through various rate recovery mechanisms over a period to be determined in future rate filings. See "Mississippi Power – Ad Valorem Tax Adjustment" herein for additional information. Southern Company Gas: Balances are recorded and recovered or amortized over periods generally not exceeding five years. In addition to natural gas cost recovery mechanisms, the natural gas distribution utilities have various other cost recovery mechanisms for the recovery of costs, including those related to infrastructure replacement programs. (f)Fuel-hedging assets and liabilities are recorded over the life of the underlying hedged purchase contracts. Upon final settlement, actual costs incurred are recovered through the applicable traditional electric operating company's fuel cost recovery mechanism. Purchase contracts generally do not exceed three and a half years for Alabama Power, three years for Georgia Power, and four years for Mississippi Power. (g)Alabama Power: Represents deferred depreciation expense for Plant Barry Unit 5 ($57 million at December 31, 2023) and Plant Barry common coal assets ($24 million at December 31, 2023) to be amortized until 2036 beginning when Plant Barry Unit 5 is retired and Plant Gaston Unit 5 coal assets ($62 million at December 31, 2023) to be amortized until 2039 beginning when the assets are retired. Georgia Power: Represents deferred depreciation expense for Plant Scherer Units 1 through 3 ($70 million at December 31, 2023) to be amortized over six years beginning in 2029 and Plant Bowen Units 1 and 2 ($40 million at December 31, 2023) to be amortized over four years beginning in 2031, both as approved under Georgia Power's 2022 ARP, and Plant Vogtle Unit 3 and common facilities ($17 million at December 31, 2023) to be amortized over a 10-year period beginning the month after Plant Vogtle Unit 4 achieves commercial operation. See "Georgia Power – Nuclear Construction – Regulatory Matters" herein for additional information on recovery of costs related to Plant Vogtle Units 3 and 4. (h)Effective January 1, 2023, Georgia Power is recovering $5 million annually for environmental remediation under the 2022 ARP. Southern Company Gas' costs are recovered through environmental cost recovery mechanisms when the remediation work is performed. See Note 3 under "Environmental Remediation" for additional information. (i)Recovered over either the remaining life of the original issue or, if refinanced, over the remaining life of the new issue. At December 31, 2023, the remaining amortization periods do not exceed 24 years for Alabama Power, 29 years for Georgia Power, 18 years for Mississippi Power, and four years for Southern Company Gas. (j)Recorded as earned by employees and recovered as paid, generally within one year. Includes both vacation and banked holiday pay, if applicable. (k)Represents certain deferred operations and maintenance costs associated with software and cloud computing projects. For Alabama Power, costs are amortized ratably over the life of the related software, which ranges up to 10 years (through 2034). See "Alabama Power – Software Accounting Order" herein for additional information. For Georgia Power, costs incurred through 2022 are being amortized over five years (through 2027) and the recovery period for costs incurred after 2022 will be determined in its next base rate case. For Mississippi Power, the recovery period will be determined in Mississippi Power's annual PEP filing process. For Southern Company Gas, costs are being amortized ratably over the life of the related software, which ranges up to 10 years (through 2034). (l)Alabama Power: Effective January 1, 2023, balance is being amortized through Rate RSE over a five-year period ending in 2027. Southern Company Gas: Represents amounts related to Nicor Gas' volume balancing adjustment rider expected to be recovered over a period of less than two years. (m)See "Georgia Power – Storm Damage Recovery" herein and Note 1 under "Storm Damage and Reliability Reserves" for additional information. Mississippi Power's balance represents deferred storm costs associated with Hurricanes Ida and Zeta being recovered through PEP over a seven-year period through 2029. (n)Nuclear outage costs are deferred to a regulatory asset when incurred and amortized over a subsequent period of 18 months for Alabama Power and up to 24 months for Georgia Power. See Note 5 for additional information. (o)Recovered over the remaining lives of the original debt issuances at acquisition, which range up to 15 years at December 31, 2023. (p)Represents deferred costs of certain repairs at Atlanta Gas Light being amortized over 20 years. (q)Represents the difference between Mississippi Power's revenue requirement for Plant Daniel Units 3 and 4 under purchase accounting and operating lease accounting. At December 31, 2023, consists of the $17 million retail portion being amortized through 2039 over the remaining life of the related property and the $8 million wholesale portion being amortized through 2035. (r)At December 31, 2023, includes $9 million of regulatory assets (wholesale) expected to be fully amortized by 2035 and $2 million of regulatory liabilities (retail) expected to be fully amortized by 2024. (s)Comprised of numerous immaterial components with remaining amortization periods at December 31, 2023 generally not exceeding 20 years for Alabama Power, 10 years for Georgia Power, 14 years for Mississippi Power, and 15 years for Southern Company Gas. (t)Utilized as related expenses are incurred. See "Alabama Power – Rate NDR" and " – Reliability Reserve Accounting Order," "Georgia Power – Storm Damage Recovery," and "Mississippi Power – System Restoration Rider" and " – Reliability Reserve Accounting Order" herein and Note 1 under "Storm Damage and Reliability Reserves" for additional information. (u)Primarily includes approximately $15 million and $62 million at December 31, 2023 and 2022, respectively, for Alabama Power and $119 million at December 31, 2022 for Georgia Power as a result of each company exceeding its allowed retail return range. Georgia Power's balances also include immaterial amounts related to refunds for transmission service customers. See "Alabama Power – Rate RSE" and "Georgia Power – Rate Plans" herein for additional information. (v)Comprised of numerous immaterial components with remaining amortization periods at December 31, 2023 generally not exceeding 11 years for Alabama Power, nine years for Georgia Power, four years for Mississippi Power, and 20 years for Southern Company Gas. (w)Generally not earning a return as they are excluded from rate base or are offset in rate base by a corresponding asset or liability. Alabama Power Alabama Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Alabama PSC. Alabama Power currently recovers its costs from the regulated retail business primarily through Rate RSE, Rate CNP, Rate ECR, and Rate NDR. In addition, the Alabama PSC issues accounting orders to address current events impacting Alabama Power. Renewable Generation Certificate Through the issuance of a Renewable Generation Certificate (RGC), Alabama Power is authorized by the Alabama PSC to procure renewable capacity and energy and to market the related energy and environmental attributes to customers and other third parties. On April 4, 2023, the Alabama PSC approved two new solar PPAs totaling 160 MWs. Upon approval of these PPAs, Alabama Power had procured solar capacity totaling approximately 490 MWs under the RGC's original 500-MW limit. On June 14, 2023, the Alabama PSC issued an order approving modifications to Alabama Power's RGC. The modifications authorized Alabama Power to procure an additional 2,400 MWs of renewable capacity and energy by June 14, 2029 and to market the related energy and environmental attributes to customers and other third parties. The modifications also increased the size of allowable renewable projects from 80 MWs to 200 MWs and increased the annual approval limit from 160 MWs to 400 MWs. Rate RSE The Alabama PSC has adopted Rate RSE that provides for periodic annual adjustments based upon Alabama Power's projected weighted common equity return (WCER) compared to an allowable range. Rate RSE adjustments are based on forward-looking information for the applicable upcoming calendar year. Rate RSE adjustments for any two-year period, when averaged together, cannot exceed 4.0% and any annual adjustment is limited to 5.0%. When the projected WCER is under the allowed range, there is an adjusting point of 5.98% and eligibility for a performance-based adder of seven basis points, or 0.07%, to the WCER adjusting point if Alabama Power (i) has an "A" credit rating equivalent with at least one of the recognized rating agencies or (ii) is in the top one-third of a designated customer value benchmark survey. Alabama Power continues to reduce growth in total debt by increasing equity, with corresponding reductions in debt issuances, thereby de-leveraging its capital structure. Alabama Power's goal is to achieve an equity ratio of approximately 55% by the end of 2025. At December 31, 2023 and 2022, Alabama Power's equity ratio was approximately 52.3% and 52.2%, respectively. Generally, during a year without a Rate RSE upward adjustment, if Alabama Power's actual WCER is between 6.15% and 7.65%, customers will receive 25% of the amount between 6.15% and 6.65%, 40% of the amount between 6.65% and 7.15%, and 75% of the amount between 7.15% and 7.65%. Customers will receive all amounts in excess of an actual WCER of 7.65%. During a year with a Rate RSE upward adjustment, if Alabama Power's actual WCER exceeds 6.15%, customers receive 50% of the amount between 6.15% and 6.90% and all amounts in excess of an actual WCER of 6.90%. Alabama Power's ability to retain a portion of the revenue that causes the actual WCER for a given year to exceed the allowed range positions Alabama Power to address the pressure on its credit quality, without increasing retail rates under Rate RSE in the near term. There is no provision for additional customer billings should the actual retail return fall below the WCER range. Retail rates under Rate RSE did not change for 2022 or 2023. For the years ended December 31, 2021, 2022, and 2023, Alabama Power's WCER exceeded 6.15%, resulting in Alabama Power establishing a current regulatory liability of $181 million, $62 million, and $15 million, respectively, for Rate RSE refunds. In accordance with an Alabama PSC order issued in February 2022, Alabama Power applied $126 million of the 2021 refund to reduce the Rate ECR under recovered balance and the remaining $55 million was refunded to customers through bill credits in July 2022. In accordance with an Alabama PSC order issued on February 7, 2023, Alabama Power refunded the 2022 amount to customers through bill credits in August 2023. The $15 million regulatory liability at December 31, 2023 will be refunded to customers through bill credits in April 2024. On December 1, 2023, Alabama Power made its required annual Rate RSE submission to the Alabama PSC of projected data for calendar year 2024. Projected earnings were within the specified range; therefore, retail rates under Rate RSE remain unchanged for 2024. Excess Accumulated Deferred Income Tax Accounting Order In December 2022, the Alabama PSC directed Alabama Power to accelerate the amortization of a regulatory liability associated with excess federal accumulated deferred income taxes. Under this order, in 2023, approximately $304 million was returned to customers through bill credits to offset the impact of the rate increase discussed under "Rate CNP Depreciation" herein. On October 3, 2023, the Alabama PSC issued an order modifying its December 2022 order and authorizing Alabama Power to (i) flow back in 2023 approximately $24 million of certain federal excess accumulated deferred income taxes resulting from the Tax Cuts and Jobs Act of 2017 and (ii) make available any remaining balance of excess accumulated deferred income taxes at the end of 2023 for the benefit of customers in 2024 and/or 2025. At December 31, 2023, the remaining balance was $81 million, of which approximately $67 million and $14 million will flow back in 2024 and 2025, respectively, for the benefit of customers. Rate CNP New Plant Rate CNP New Plant allows for recovery of Alabama Power's retail costs associated with newly developed or acquired certificated generating facilities placed into retail service. No adjustments to Rate CNP New Plant occurred during the period January 2021 through October 2022. In July 2022, the Alabama PSC approved a CCN authorizing Alabama Power to complete the acquisition of the Calhoun Generating Station. The transaction closed in September 2022 and, in October 2022, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover the related costs. The filing reflected an increase in annual revenues of $34 million, or 0.6%, effective with November 2022 billings. In 2020, the Alabama PSC approved a CCN authorizing Alabama Power to complete the acquisition of the Central Alabama Generating Station, which occurred in August 2020. Through May 2023, Alabama Power recovered substantially all costs associated with the Central Alabama Generating Station through Rate RSE, offset by revenues from a power sales agreement. Beginning in July 2022, fuel costs associated with Central Alabama Generating Station are being recovered through Rate ECR. On March 24, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of the Central Alabama Generating Station. The filing reflected an annual increase in retail revenues of $78 million, or 1.1%, effective with June 2023 billings. On May 24, 2023, the Central Alabama Generating Station was placed into retail service. The Alabama PSC's 2020 CCN also authorized Alabama Power to construct an approximately 720-MW combined cycle facility at Alabama Power's Plant Barry (Plant Barry Unit 8) and the recovery of estimated in-service costs. On November 1, 2023, the unit was placed in service. On December 1, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover the related costs. The filing reflected an annual increase in retail revenues of $91 million, or 1.4%, effective with January 2024 billings. Rate CNP PPA Rate CNP PPA allows for the recovery of Alabama Power's retail costs associated with certificated PPAs. Revenues for Rate CNP PPA, as recorded on the financial statements, are adjusted for differences in actual recoverable costs and amounts billed in current regulated rates. Accordingly, changes in the billing factors will have no significant effect on Southern Company's or Alabama Power's revenues or net income but will affect annual cash flow. No adjustments to Rate CNP PPA occurred during the period 2021 through 2023 and no adjustment is expected for 2024. At December 31, 2023 and 2022, Alabama Power had an under recovered Rate CNP PPA balance of $103 million and $120 million, respectively, of which $18 million and $18 million, respectively, is included in other regulatory assets, current and $85 million and $102 million, respectively, is included in other regulatory assets, deferred on the balance sheet. Rate CNP Compliance Rate CNP Compliance allows for the recovery of Alabama Power's retail costs associated with laws, regulations, and other such mandates directed at the utility industry involving the environment, security, reliability, safety, sustainability, or similar considerations impacting Alabama Power's facilities or operations. Rate CNP Compliance is based on forward-looking information and provides for the recovery of these costs pursuant to factors that are calculated and submitted to the Alabama PSC by December 1 with rates effective for the following calendar year. Compliance costs to be recovered include operations and maintenance expenses, depreciation, and a return on certain invested capital. Revenues for Rate CNP Compliance, as recorded on the financial statements, are adjusted for differences in actual recoverable costs and amounts billed in current regulated rates. Accordingly, changes in the billing factors will have no significant effect on Southern Company's or Alabama Power's revenues or net income, but will affect annual cash flow. Changes in Rate CNP Compliance-related operations and maintenance expenses and depreciation generally will have no effect on net income. In November 2021, December 2022, and December 2023, Alabama Power submitted calculations to the Alabama PSC associated with its cost of complying with governmental mandates for the following calendar year, as provided under Rate CNP Compliance. The 2021 filing reflected a projected under recovered retail revenue requirement of approximately $59 million. In December 2021, the Alabama PSC issued a consent order that Alabama Power leave the 2021 Rate CNP Compliance factors in effect for 2022, with any prior year under collected amount deemed recovered before any current year amounts are recovered and any remaining under recovery reflected in the 2022 filing. The 2022 filing reflected a $255 million, or 3.7%, annual increase effective with January 2023 billings, primarily due to updated depreciation rates. The 2023 filing reflected a $23 million, or 0.3%, annual decrease effective with January 2024 billings. At December 31, 2023, Alabama Power had an under recovered Rate CNP Compliance balance of $33 million, of which $8 million is included in other regulatory assets, current and $25 million is included in other regulatory assets, deferred on the balances sheet, compared to an under recovered balance at December 31, 2022 of $47 million included in other regulatory assets, current on the balance sheet. Rate CNP Depreciation In December 2022, the Alabama PSC approved Rate CNP Depreciation, which allows Alabama Power to recover changes in depreciation resulting from updates to certain depreciation rates, excluding any depreciation recovered through Rate CNP New Plant, Rate CNP Compliance, or costs associated with the capitalization of asset retirement costs. Rate CNP Depreciation resulted in an annual revenue increase of approximately $318 million, or 4.6%, effective with January 2023 billings. See "Excess Accumulated Deferred Income Tax Accounting Order" herein for information related to 2023 customer bill credits approved by the Alabama PSC. Rate ECR Rate ECR recovers Alabama Power's retail energy costs based on an estimate of future energy costs and the current over or under recovered balance. Revenues recognized under Rate ECR and recorded on the financial statements are adjusted for the difference in actual recoverable fuel costs and amounts billed in current regulated rates. The difference in the recoverable fuel costs and amounts billed gives rise to the over or under recovered amounts recorded as regulatory assets or liabilities. Alabama Power, along with the Alabama PSC, continually monitors the over or under recovered cost balance to determine whether an adjustment to billing rates is required. Changes in the Rate ECR factor have no significant effect on Southern Company's or Alabama Power's net income but will impact the related operating cash flows. The Alabama PSC may approve billing rates under Rate ECR of up to 5.910 cents per KWH. The Alabama PSC approved adjustments to Rate ECR from 1.960 cents per KWH to 2.557 cents per KWH, or approximately $310 million annually, effective with August 2022 billings and from 2.557 cents per KWH to 3.510 cents per KWH, or approximately $500 million annually, effective with December 2022 billings. On November 9, 2023, the Alabama PSC approved a decrease to Rate ECR from 3.510 cents per KWH to 3.270 cents per KWH, or approximately $126 million annually, effective with December 2023 billings. The rate will adjust to 5.910 cents per KWH in January 2025 absent a further order from the Alabama PSC. At December 31, 2023 and 2022, Alabama Power's under recovered fuel costs totaled $246 million and $622 million, respectively, of which $246 million and $102 million, respectively, is included in regulatory assets – under recovered retail fuel clause revenues and $520 million of the December 31, 2022 balance is included in other regulatory assets, deferred on the balance sheets. These classifications are based on estimates, which include such factors as weather, generation availability, energy demand, and the price of energy. A change in any of these factors could have a significant impact on the timing of any recovery or return of fuel costs. Software Accounting Order The Alabama PSC authorizes Alabama Power to establish a regulatory asset for operations and maintenance costs associated with software implementation projects. The regulatory asset is amortized ratably over the life of the related software. At December 31, 2023 and 2022, the regulatory asset balance totaled $59 million and $46 million, respectively, and is included in other regulatory assets, deferred on the balance sheet. Plant Greene County Alabama Power jointly owns Plant Greene County with an affiliate, Mississippi Power. See Note 5 under "Joint Ownership Agreements" for additional information. In 2021, the Mississippi PSC concluded its review of Mississippi Power's 2021 IRP, which included a schedule to retire Mississippi Power's 40% ownership interest in Plant Greene County Units 1 and 2 in December 2025 and 2026, respectively, consistent with each unit's remaining useful life. Alabama Power and Mississippi Power have continued to evaluate operating conditions and business needs relevant to the anticipated retirement of Plant Greene County and now expect the units to remain in service beyond the previously indicated dates. The Plant Greene County unit retirements require the completion by Alabama Power of transmission and system reliability improvements, as well as agreement by Alabama Power. The ultimate outcome of this matter cannot be determined at this time. See "Mississippi Power – Integrated Resource Plan" herein for additional information. Rate NDR Based on an order from the Alabama PSC, Alabama Power maintains a reserve for operations and maintenance expenses to cover the cost of damages from major storms to its transmission and distribution facilities. The order approves a separate monthly Rate NDR charge to customers consisting of two components. The first component is intended to establish and maintain a reserve balance for future storms and is an on-going part of customer billing. When the reserve balance falls below $50 million, a reserve establishment charge will be activated (and the on-going reserve maintenance charge concurrently suspended) until the reserve balance reaches $75 million. The second component of the Rate NDR charge is intended to allow recovery of any existing deferred storm-related operations and maintenance costs and any future reserve deficits over a 48-month period (24-month period prior to modifications approved by the Alabama PSC in July 2022). The Alabama PSC order gives Alabama Power authority to record a deficit balance in the NDR when costs of storm damage exceed any established reserve balance. The maximum total Rate NDR charge was limited to $10.00 per month per non-residential customer account and $5.00 per month per residential customer account through July 12, 2022. Subsequently, modifications approved by the Alabama PSC replaced the maximum total Rate NDR charge with a maximum charge to recover a deficit of $5 per month per non-residential customer account and $2.50 per month per residential customer account. Alabama Power has the authority, based on an order from the Alabama PSC, to accrue certain additional amounts as circumstances warrant, which can be used to offset storm charges. Alabama Power made an additional accrual of $65 million in 2021. Alabama Power collected approximately $12 million, $14 million, and $6 million in 2023, 2022, and 2021, respectively, under Rate NDR. Beginning with August 2022 billings, the reserve establishment charge was suspended and the reserve maintenance charge was activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect approximately $12 million annually under Rate NDR unless the NDR balance falls below $50 million. At December 31, 2023 and 2022, the NDR balance was $76 million and $97 million, respectively, and is included in other regulatory liabilities, deferred on the balance sheets. As revenue from the Rate NDR charge is recognized, an equal amount of operations and maintenance expenses related to the NDR will also be recognized. As a result, the Rate NDR charge will not have an effect on net income but will impact operating cash flows. Reliability Reserve Accounting Order In July 2022, the Alabama PSC approved an accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million. At December 31, 2023 and 2022, Alabama Power accrued $52 million and $166 million, respectively, to the reserve. On July 11, 2023, the Alabama PSC issued an order authorizing Alabama Power to expand the existing authority of its reliability reserve to include certain production-related expenses that are intended to maintain reliability in between scheduled generating unit maintenance outages. On August 18, 2023, Alabama Power notified the Alabama PSC of its intent to use a portion of its reliability reserve balance in 2023. During the fourth quarter 2023, Alabama Power used $75 million of the reliability reserve for reliability-related transmission, distribution, and generation expenses and nuclear production-related expenses. At December 31, 2023 and 2022, Alabama Power's reliability reserve balance was $143 million and $166 million, respectively, and is included in other regulatory liabilities, deferred on the balance sheets. Environmental Accounting Order Based on an order from the Alabama PSC (Environmental Accounting Order), Alabama Power is authorized to establish a regulatory asset to record the unrecovered investment costs, including the unrecovered plant asset balance and the unrecovered costs associated with site removal and closure associated with future unit retirements caused by environmental regulations. The regulatory asset is amortized and recovered over the affected unit's remaining useful life, as established prior to the decision regarding early retirement, through Rate CNP Compliance. With the completion of the Calhoun Generating Station acquisition, Alabama Power expected to retire Plant Barry Unit 5 in late 2023 or early 2024, subject to certain operating conditions. In September 2022, Alabama Power reclassified approximately $600 million for Plant Barry Unit 5 from plant in service, net of depreciation to other utility plant, net and will continue to depreciate the asset according to the original depreciation rates. Alabama Power has continued to evaluate operating conditions relevant to the expected retirement of Plant Barry Unit 5 and now expects to retire the unit on or before December 31, 2028. At retirement, Alabama Power will reclassify the remaining net investment costs of the unit to a regulatory asset to be recovered over the unit's remaining useful life, as established prior to the decision to retire, through Rate CNP Compliance. See "Rate CNP New Plant" herein for additional information. In December 2022, in conjunction with Alabama Power's compliance plan for the EPA's final steam electric ELG reconsideration rule, Plant Barry Unit 4 ceased using coal and began operating solely on natural gas. As a result, approximately $42 million of plant in service, net of depreciation was reclassified to a regulatory asset to be recovered through Rate CNP Compliance through 2034, the unit's remaining useful life. Georgia Power Georgia Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Georgia PSC. Georgia Power recovers its costs from the regulated retail business through traditional base tariffs, Demand-Side Management (DSM) tariffs, the ECCR tariff, and Municipal Franchise Fee (MFF) tariffs. These tariffs were set under the 2019 ARP for the years 2020 through 2022 and under the 2022 ARP for the years 2023 through 2025 as described herein. In addition, fuel costs are collected through a separate fuel cost recovery tariff. See "Nuclear Construction – Regulatory Matters" herein for information regarding the approved recovery through retail base rates of certain costs related to Plant Vogtle Unit 3 and the common facilities shared between Plant Vogtle Units 3 and 4 (Common Facilities) that became effective August 1, 2023 based on the in-service date of July 31, 2023 for Unit 3, as well as the base rate adjustments that will occur the first day of the month after Unit 4 achieves commercial operation. Financing costs on certified construction costs of Plant Vogtle Units 3 and 4 that are not included in rate base are being collected through Georgia Power's NCCR tariff. When the base rate adjustments occur following commercial operation of Unit 4, the NCCR tariff will cease to be collected and financing costs will be included in Georgia Power's general retail revenue requirements. See "Nuclear Construction" herein for additional information on Plant Vogtle Units 3 and 4. Rate Plans 2022 ARP In December 2022, the Georgia PSC voted to approve the 2022 ARP, under which Georgia Power increased its rates on January 1, 2023. On November 16, 2023, the Georgia PSC approved tariff adjustments effective January 1, 2024. Details of tariff adjustments are provided in the following table:
Tariff | 2023 |  | 2024
| (in millions)
Traditional base | $ 194 |  | $ 275
ECCR | (21) |  | (99)
DSM | 37 |  | 10
MFF | 6 |  | 5
Total | $ 216 |  | $ 191
Under the 2022 ARP, Georgia Power will adjust traditional base, ECCR, DSM, and MFF rates effective January 1, 2025, with the incremental revenue requirements related to DSM tariffs and CCR AROs subject to updates through annual compliance filings to be made at least 90 days prior to the effective date. In the 2022 ARP, the Georgia PSC approved recovery through the ECCR tariff of estimated CCR ARO compliance costs for 2023, 2024, and 2025 over four-year periods beginning January 1 of each respective year, with recovery of construction contingency beginning in the year following actual expenditures, resulting in $60 million and $20 million reductions in the related amortization expense for 2024 and 2023, respectively. Compliance costs incurred were $300 million in 2023 and are expected to be $305 million and $330 million in 2024 and 2025, respectively. The CCR ARO costs are expected to be revised for actual expenditures and updated estimates through future annual compliance filings. Further, under the 2022 ARP, Georgia Power's retail ROE is set at 10.50% and its equity ratio is set at 56%. Earnings will be evaluated against a retail ROE range of 9.50% to 11.90%. Any retail earnings above 11.90% will be shared, with 40% being applied to reduce regulatory assets, 40% directly refunded to customers, and the remaining 20% retained by Georgia Power. There will be no recovery of any earnings shortfall below 9.50% on an actual basis. However, if at any time during the term of the 2022 ARP, Georgia Power projects that its retail earnings will be below 9.50% for any calendar year, it may petition the Georgia PSC for implementation of the Interim Cost Recovery (ICR) tariff to adjust Georgia Power's retail rates to achieve a 9.50% ROE. The Georgia PSC would have 90 days to rule on Georgia Power's request. The ICR tariff would expire at the earlier of January 1, 2026 or the end of the calendar year in which the ICR tariff becomes effective. In lieu of requesting implementation of an ICR tariff, or if the Georgia PSC chooses not to implement the ICR tariff, Georgia Power may file a full rate case. In 2023, Georgia Power's retail ROE was within the allowed retail ROE range. Except as provided above, Georgia Power will not file for a general base rate increase while the 2022 ARP is in effect. Georgia Power is required to file a general base rate case by July 1, 2025, in response to which the Georgia PSC would be expected to determine whether the 2022 ARP should be continued, modified, or discontinued. 2019 ARP The Georgia PSC approved the following tariff adjustments under the 2019 ARP effective January 1 2022:
Tariff | 2022
| (in millions)
Traditional base | $ 192
ECCR | (12)
DSM | (25)
MFF | 2
Total | $ 157
In the 2019 ARP, the Georgia PSC approved recovery through the ECCR tariff of the estimated under recovered balance of CCR ARO compliance costs. Under the 2019 ARP, the under recovered balance at December 31, 2019 and compliance costs for 2020 were recovered over the three-year period ended December 31, 2022. Recovery of estimated compliance costs for 2021 and 2022 are being recovered over four-year periods beginning January 1 of each respective year, as authorized under the 2019 ARP and modified under the 2022 ARP, with recovery of construction contingency beginning in the year following actual expenditure. The CCR ARO costs recovered through the ECCR tariff are revised for actual expenditures and updated estimates through annual compliance filings, which resulted in an approximate $10 million increase effective January 1, 2022 in the related cost recovery. Georgia Power's retail ROE under the 2019 ARP was set at 10.50% and earnings were evaluated against a retail ROE range of 9.50% to 12.00%. Any retail earnings above 12.00% were shared, with 40% applied to reduce regulatory assets, 40% directly refunded to customers, and the remaining 20% retained by Georgia Power. In 2020, Georgia Power's retail ROE was within the allowed retail ROE range. In 2021, Georgia Power's retail ROE exceeded 12.00%, and Georgia Power reduced regulatory assets by approximately $5 million and accrued approximately $5 million which was refunded to customers in 2022. In 2022, Georgia Power's retail ROE exceeded 12.00%, and Georgia Power reduced regulatory assets by $117 million and refunded $117 million to customers through bill credits in the first quarter 2023. Integrated Resource Plans In July 2022, the Georgia PSC approved Georgia Power's 2022 IRP, as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved, among other things, the certification of six PPAs (including five affiliate PPAs with Southern Power that are subject to approval by the FERC) with capacities of 1,567 MWs beginning in 2024, 380 MWs beginning in 2025, and 228 MWs beginning in 2028, procured through RFPs authorized in the 2019 IRP. See Note 9 for additional information. On October 27, 2023, Georgia Power filed an updated IRP (2023 IRP Update) with the Georgia PSC, which sets forth a plan to support the recent increase in the state of Georgia's projected energy needs since the 2022 IRP. In the 2023 IRP Update, Georgia Power requested the following: *Authority to develop, own, and operate up to 1,400 MWs from three simple cycle combustion turbines at Plant Yates. *Certification of an affiliate PPA with Mississippi Power for 750 MWs, which began January 1, 2024 and will continue through December 2028. *Certification of a non-affiliate PPA for 230 MWs starting the month after conclusion of the 2023 IRP Update proceeding continuing through December 2028. *Authority to develop, own, and operate up to 1,000 MWs of battery energy storage system facilities, including storage systems collocated with existing and new Georgia Power-owned solar facilities. *Approval of transmission projects necessary to support the generation resources requested in the 2023 IRP Update. The 2023 IRP Update assumes a retirement date at the end of 2035 for Plant Bowen Units 1 and 2 (1,400 MWs). Georgia Power expects to make a formal recommendation in the 2025 IRP on the retirement or continued operations for Plant Bowen Units 1 and 2, as well as evaluate extending the operation of Plant Scherer Unit 3 (614 MWs based on 75% ownership) and Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) beyond the retirement dates in 2028 that were approved in the 2022 IRP. See Note 7 under "SEGCO" for additional information. Georgia Power expects the Georgia PSC to render a final decision on the 2023 IRP Update on April 16, 2024. On January 12, 2024, Georgia Power entered into an Agreement for Engineering, Procurement, and Construction with Mitsubishi Power Americas, Inc. and Black & Veatch Construction, Inc. to construct three 442-MW simple cycle combustion turbine units at Plant Yates (Plant Yates Units 8, 9, and 10), which are expected to be placed in service in the fourth quarter 2026, the second quarter 2027, and the third quarter 2027, respectively. See Note 17 under "Georgia Power – Integrated Resource Plans" for additional information. The ultimate outcome of these matters cannot be determined at this time. In August 2022, Restore Chattooga Gorge Coalition (RCG) filed a petition in the Superior Court of Fulton County, Georgia against Georgia Power and the Georgia PSC. The petition challenged Georgia Power's plan to expend $115 million to modernize Plant Tugalo (a hydro facility), as approved in the 2019 IRP, and sought judicial review of the Georgia PSC's order in the 2022 IRP proceeding with respect to the denial of RCG's challenge to the modernization plan. On October 23, 2023, the court granted Georgia Power's and the Georgia PSC's motions to dismiss the RCG petition. This matter is now concluded. Fuel Cost Recovery Georgia Power has established fuel cost recovery rates approved by the Georgia PSC. During the second half of 2021, the price of natural gas rose significantly and resulted in an under recovered fuel balance exceeding $200 million. Therefore, in November 2021, the Georgia PSC voted to approve Georgia Power's interim fuel rider, which increased fuel rates by 15%, or approximately $252 million annually, effective January 1, 2022. During 2022, Georgia Power's under recovered fuel balance continued to increase significantly due to higher fuel and purchased power costs. On May 16, 2023, the Georgia PSC approved a stipulation agreement between Georgia Power and the staff of the Georgia PSC to increase annual fuel billings by 54%, or approximately $1.1 billion, effective June 1, 2023. The increase includes a three-year recovery period for $2.2 billion of Georgia Power's under recovered fuel balance at May 31, 2023. Under the approved stipulation agreement, Georgia Power is allowed to adjust its fuel cost recovery rates under an interim fuel rider prior to the next fuel case, subject to a maximum 40% cumulative change, if its under or over recovered fuel balance accumulated since May 31, 2023 exceeds $200 million. Georgia Power is scheduled to file its next fuel case no later than February 28, 2026. Georgia Power's under recovered fuel balance totaled $1.9 billion at December 31, 2023, of which $694 million is included in under recovered fuel clause revenues and under recovered retail fuel clause revenues on Southern Company's and Georgia Power's balance sheets, respectively, and $1.2 billion is included in deferred under recovered retail fuel clause revenues on Southern Company's and Georgia Power's balance sheets. The under recovered fuel balance totaled $2.1 billion at December 31, 2022 and is included in deferred under recovered retail fuel clause revenues on Southern Company's and Georgia Power's balance sheets. Georgia Power's fuel cost recovery mechanism includes costs associated with a natural gas hedging program, as revised and approved by the Georgia PSC, allowing the use of an array of derivative instruments within a 36-month time horizon. Fuel cost recovery revenues as recorded on the financial statements are adjusted for differences in actual recoverable fuel costs and amounts billed in current regulated rates. Accordingly, changes in the billing factor will not have a significant effect on Southern Company's or Georgia Power's revenues or net income but will affect operating cash flows. Storm Damage Recovery Georgia Power defers and recovers certain costs related to damages from major storms as mandated by the Georgia PSC. During 2021 and 2022, Georgia Power recovered $213 million annually under the 2019 ARP. Beginning January 1, 2023, Georgia Power is recovering $31 million annually under the 2022 ARP. At December 31, 2022, Georgia Power's storm damage reserve balance was $83 million and is included in other regulatory liabilities, deferred on Southern Company's balance sheet and other deferred credits and liabilities on Georgia Power's balance sheet. During 2023, significant storms caused damage to Georgia Power's transmission and distribution facilities. The incremental restoration costs related to these storms exceeded the storm damage reserve and were deferred in the regulatory asset for storm damage. At December 31, 2023, Georgia Power's regulatory asset balance related to storm damage was $54 million, of which $31 million is included in other regulatory assets, current and $23 million is included in other regulatory assets, deferred on Southern Company's and Georgia Power's balance sheets. The rate of storm damage cost recovery is expected to be adjusted in future regulatory proceedings as necessary. As a result of this regulatory treatment, costs related to storms are not expected to have a material impact on Southern Company's or Georgia Power's net income but do impact the related operating cash flows. See Note 1 under "Storm Damage and Reliability Reserves" for additional information. Nuclear Construction In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement. In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, under which Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. See Note 8 under "Long-term Debt – DOE Loan Guarantee Borrowings" for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events. Cost and Schedule Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the second quarter 2024 is as follows:
| (in millions)
Base project capital cost forecast(a)(b) | $ 10,717
Construction contingency estimate | 36
Total project capital cost forecast(a)(b) | 10,753
Net investment at December 31, 2023(b) | (10,564)
Remaining estimate to complete | $ 189
(*)Includes approximately $610 million of costs that are not shared with the other Vogtle Owners, including $33 million of construction monitoring costs, and approximately $567 million of incremental costs under the cost-sharing provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $440 million, of which $417 million had been accrued through December 31, 2023. (*)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds. Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.53 billion, of which $3.50 billion had been incurred through December 31, 2023. Georgia Power placed Unit 3 in service on July 31, 2023. As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts for Unit 4 on a regular basis to incorporate current information available, particularly in the areas of start-up testing and related test results and engineering support. As of December 31, 2023, based on completion of construction work and the assessment of start-up and pre-operational testing remaining, Southern Nuclear has an estimated $36 million for construction contingency remaining in the estimate to complete. This contingency is projected to be allocated in the future to address any further Unit 4 schedule extensions or remediation of other issues discovered during start-up testing. Hot functional testing for Unit 4 was completed on May 1, 2023. On July 20, 2023, Southern Nuclear announced that all Unit 4 ITAACs had been submitted to the NRC, and, on July 28, 2023, the NRC published its 103(g) finding that the accepted criteria in the combined license for Unit 4 had been met, which allowed nuclear fuel to be loaded and start-up testing to begin. Fuel load for Unit 4 was completed on August 19, 2023. On October 6, 2023, Georgia Power announced that during start-up and pre-operational testing for Unit 4, Southern Nuclear identified a motor fault in one of four reactor coolant pumps (RCPs). This RCP was replaced with an on-site spare RCP from inventory. On February 1, 2024, Georgia Power announced that during start-up and pre-operational testing for Unit 4, Southern Nuclear identified, and has remediated, vibrations associated with certain piping within the cooling system. Considering the remaining pre-operational testing, Unit 4 is projected to be placed in service during the second quarter 2024. On February 14, 2024, Unit 4 achieved self-sustaining nuclear fission, commonly referred to as initial criticality. With Unit 3's four RCPs operating as designed, Southern Nuclear believes that the motor fault on this single Unit 4 RCP is an isolated event. However, any findings related to the root cause of the motor fault on the single Unit 4 RCP could require engineering changes or remediation related to the other seven Unit 3 and Unit 4 RCPs. The projected schedule for Unit 4 significantly depends on the progression of start-up and pre-operational testing, which may be impacted by equipment or other operational failures. As Unit 4 progresses further through testing, ongoing and potential future challenges may also include the management of contractors and vendors; the availability of materials and parts, and/or related cost escalation; the availability of supervisory and technical support resources; and the timeframe and duration of pre-operational testing. New challenges also may continue to arise as Unit 4 moves further into testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last several years began initial operation in the global nuclear industry at this scale). These challenges may result in further schedule delays and/or cost increases. With the receipt of the NRC's 103(g) findings for Units 3 and 4 in August 2022 and July 2023, respectively, the site is subject to the NRC's operating reactor oversight process and must meet applicable technical and operational requirements contained in its operating license. Various design and other licensing-based compliance matters may result in additional license amendment requests or require other resolution. If any license amendment requests or other licensing-based compliance issues are not resolved in a timely manner, there may be delays in the Unit 4 project schedule that could result in increased costs. The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond June 2024 for Unit 4, including the joint owner cost sharing impacts described below, is estimated to result in additional base capital costs for Georgia Power of up to $25 million per month as well as any additional related construction, support resources, or testing costs. Pursuant to the regulatory orders discussed below, any further changes to the capital cost forecast will not be recoverable through regulated rates and will be required to be charged to income. Such charges could be material. See Note 17 under "Georgia Power – Nuclear Construction" for additional information. Joint Owner Contracts In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct. Amendments to the Vogtle Joint Ownership Agreements In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments). Pursuant to the Global Amendments: (i) each Vogtle Owner paid its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4, of which Georgia Power's share is $8.4 billion (VCM 19 Forecast Amount), plus $800 million; (ii) Georgia Power was responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the VCM 19 Forecast Amount (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power was responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the VCM 19 Forecast Amount (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. The Global Amendments provide that if the EAC was revised and exceeded the VCM 19 Forecast Amount by more than $2.1 billion, each of the other Vogtle Owners had a one-time option at the time the project budget cost forecast was so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the VCM 19 Forecast Amount plus $2.1 billion. In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events (Project Adverse Events) occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction and all the Vogtle Owners voted to continue construction. The filing of Georgia Power's prudency application with the Georgia PSC, which included Georgia Power's public announcement of its intention not to submit for rate recovery an amount that is greater than the first 6% of costs during any six-month VCM reporting period, triggered the requirement for a vote to continue construction and all the Vogtle Owners voted to continue construction. See additional information on Georgia Power's prudency application filing below. In September 2022, Georgia Power and MEAG Power reached an agreement to resolve a dispute regarding the cost-sharing and tender provisions of the Global Amendments. Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power's costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will reimburse 20% of MEAG Power's costs of construction with respect to any amounts over the current project capital cost forecast, with no further adjustment for force majeure costs. In addition, MEAG Power agreed to vote to continue construction upon occurrence of a Project Adverse Event unless the commercial operation date of either of Plant Vogtle Unit 3 or Unit 4 is not projected to occur by December 31, 2025. On October 5, 2023 and October 17, 2023, Georgia Power reached agreements with OPC and Dalton, respectively, to resolve its respective dispute with each of OPC and Dalton regarding the cost-sharing and tender provisions of the Global Amendments. Under the terms of the agreements with OPC and Dalton, among other items, (i) each of OPC and Dalton retracted its exercise of the tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4, (ii) Georgia Power made payments immediately after execution of the agreements of $308 million and $17 million to OPC and Dalton, respectively, representing payment for a portion of each of OPC's and Dalton's costs of construction for Plant Vogtle Units 3 and 4 previously incurred, (iii) Georgia Power will pay a portion of each of OPC's and Dalton's further costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which payments will be in an aggregate amount of approximately $105 million and $6 million for OPC and Dalton, respectively, based on the current project capital cost forecast, and (iv) Georgia Power will pay 66% of each of OPC's and Dalton's costs of construction with respect to any amounts above the current project capital cost forecast, with no further adjustment for force majeure costs. Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated with the cost-sharing provisions of the Global Amendments, including the settlement with MEAG Power. Based on the current project capital cost forecast and the settlements with OPC and Dalton described above, Georgia Power recorded a pre-tax charge to income of approximately $160 million ($120 million after tax) in the third quarter 2023. These charges are included in the total project capital cost forecast and will not be recovered from retail customers. The ultimate impact of these matters on the project capital cost forecast for Plant Vogtle Units 3 and 4 cannot be determined at this time. Regulatory Matters In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At December 31, 2023, Georgia Power had recovered approximately $3.0 billion of financing costs. Financing costs related to capital costs above $4.418 billion up to $7.562 billion approved for recovery as described below are being recognized through AFUDC and will be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of $7.562 billion. In December 2022, the Georgia PSC approved Georgia Power's filing to increase the NCCR tariff by $36 million annually, effective January 1, 2023. On November 1, 2023, Georgia Power filed a request to continue for 2024 the NCCR tariff that was effective during 2023. The staff of the Georgia PSC accepted the proposal and no further approval from the Georgia PSC was required. See additional information below on AFUDC and the NCCR tariff following commercial operation of Unit 4. In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In January 2018, the Georgia PSC issued an order approving Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 2018 order, resolved certain regulatory matters related to Plant Vogtle Units 3 and 4 including, but not limited to: (i) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (ii) confirmed that a prudence proceeding on cost recovery would occur following Unit 4 fuel load, consistent with applicable Georgia law; (iii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC at that time) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); and (iv) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018. The January 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $310 million, $300 million, and $270 million in 2023, 2022, and 2021, respectively, and are estimated to have a negative earnings impact of approximately $90 million in 2024. In 2021, the Georgia PSC approved an order under which Georgia Power would include in rate base an allocation of $2.1 billion to Plant Vogtle Unit 3 and the Common Facilities from the $3.6 billion of Plant Vogtle Units 3 and 4 costs previously deemed prudent by the Georgia PSC and would recover the related depreciation expense through retail base rates effective the month after Unit 3 is placed in service. In compliance with the Georgia PSC order, Georgia Power increased annual retail base rates by $318 million effective August 1, 2023 based on the in-service date of July 31, 2023 for Unit 3. The related increase in annual retail base rates included recovery of all projected operations and maintenance expenses for Unit 3 and the Common Facilities and other related costs of operation, partially offset by the related PTCs. Financing costs (debt and equity) on the remaining portion of the total Unit 3 and the Common Facilities construction costs continue to be recovered through the NCCR tariff or deferred. Georgia Power is deferring as a regulatory asset the debt component of financing costs ($14 million at December 31, 2023) as well as the remaining depreciation expense ($17 million at December 31, 2023) until Unit 4 costs are placed in retail base rates. The equity component of financing costs ($23 million at December 31, 2023) represents an unrecognized ratemaking amount that is not reflected on Georgia Power's balance sheets. This amount will be recognized in Georgia Power's income statements in the periods it is billable to customers. On August 19, 2023, fuel load for Unit 4 was completed, and, on August 30, 2023, Georgia Power filed an application to adjust rates to include reasonable and prudent Plant Vogtle Units 3 and 4 costs (Application). On December 19, 2023, the Georgia PSC voted to approve the Application as modified by the related stipulated agreement (Prudency Stipulation) among Georgia Power, the staff of the Georgia PSC, and certain intervenors. While recognizing the Prudency Stipulation, the Application provided the necessary support to justify the reasonableness, prudence, and recovery of $8.826 billion in total construction and capital costs, $1.07 billion in associated retail rate base items, and the operating costs related to the full operation and output of Plant Vogtle Units 3 and 4. Under the terms of the approved Prudency Stipulation, Georgia Power will recover $7.562 billion in total construction and capital costs and associated retail rate base items of $1.02 billion, which includes AFUDC financing costs above $4.418 billion (the Georgia PSC-certified amount) up to $7.562 billion. Georgia Power will also recover projected operations and maintenance expenses, depreciation expense, nuclear decommissioning accruals, and property taxes, net of projected PTCs. After considering construction and capital costs already in retail base rates of $2.1 billion and $362 million of associated retail rate base items (approved by the Georgia PSC in 2021) and upon achieving commercial operation of Unit 4, Georgia Power will include in retail rate base the remaining $5.462 billion of construction and capital costs as well as $656 million of associated retail rate base items. When the rate adjustment occurs, Georgia Power's NCCR tariff will cease to be collected and financing costs will be included in Georgia Power's general retail revenue requirements. Further, as included in the approved Prudency Stipulation, if commercial operation for Unit 4 is not achieved by March 31, 2024, Georgia Power's ROE used to determine the NCCR tariff and calculate AFUDC will be reduced to zero, which will result in an estimated negative impact to earnings of approximately $30 million per month until the month following the date commercial operation for Unit 4 is achieved. As of each Unit's respective first refueling outage, if the respective Unit's performance has materially deviated from expected performance, the Georgia PSC may order Georgia Power to credit customers for operations and maintenance expenses or disallow costs associated with the repair or replacement of any system, structure, or component found to have caused the material deviation in performance if proven to be the result of imprudent engineering, construction, procurement, testing, or start-up. Annual retail base revenues will increase approximately $729 million and the average retail base rates will be adjusted by approximately 5% (net of the elimination of the NCCR tariff described above) effective the first day of the month after Unit 4 achieves commercial operation. The approval of the Application and the Prudency Stipulation resolves all issues for determination by the Georgia PSC regarding the reasonableness, prudence, and cost recovery for the remaining Plant Vogtle Units 3 and 4 construction and capital costs not already in retail base rates. As a result of the Georgia PSC's approval of the Prudency Stipulation, Georgia Power recorded a pre-tax credit to income of approximately $228 million ($170 million after tax) in the fourth quarter 2023 to recognize CWIP costs previously charged to income, which are now recoverable through retail rates. Associated AFUDC on these costs was also recognized. The ultimate outcome of these matters cannot be determined at this time. Mississippi Power Mississippi Power's rates and charges for service to retail customers are subject to the regulatory oversight of the Mississippi PSC. Mississippi Power's rates are a combination of base rates and several separate cost recovery clauses for specific categories of costs. These separate cost recovery clauses address such items as fuel and purchased power, ad valorem taxes, property damage, and the costs of compliance with environmental laws and regulations. Costs not addressed through one of the specific cost recovery clauses are expected to be recovered through Mississippi Power's base rates. Performance Evaluation Plan Mississippi Power's retail base rates generally are set under the PEP, a rate plan approved by the Mississippi PSC. In recognition that Mississippi Power's long-term financial success is dependent upon how well it satisfies its customers' needs, PEP includes performance indicators that directly tie customer service indicators to Mississippi Power's allowed ROE. PEP measures Mississippi Power's performance on a 10-point scale as a weighted average of results in three areas: average customer price, as compared to prices of other regional utilities (weighted at 40%); service reliability, measured in percentage of time customers had electric service (40%); and customer satisfaction, measured in a survey of residential customers (20%). Typically, two PEP filings are made for each calendar year: the PEP projected filing in March of the current year and the PEP lookback filing in March of the subsequent year. The annual PEP projected filings utilize a historic test year adjusted for "known and measurable" changes and discounted cash flow and regression formulas to determine base ROE. The PEP lookback filing reflects the actual revenue requirement. In June 2021 and June 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filings, resulting in annual increases in revenues of approximately $16 million, or 1.8%, and $18 million, or 1.9%, respectively, effective with the first billing cycle of April 2021 and April 2022, respectively. On June 13, 2023, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2023 indicating no change in retail rates. Integrated Resource Plan In 2020, the Mississippi PSC issued an order requiring Mississippi Power to incorporate into its 2021 IRP a schedule of early or anticipated retirement of 950 MWs of fossil-steam generation by year-end 2027 to reduce the excess reserve margin Mississippi Power anticipated at that time. The order stated that Mississippi Power will be allowed to defer any retirement-related costs as regulatory assets for future recovery. In 2021, the Mississippi PSC concluded its review of Mississippi Power's 2021 IRP. The 2021 IRP included a schedule to retire Plant Watson Unit 4 (268 MWs) and Mississippi Power's 40% ownership interest in Plant Greene County Units 1 and 2 (103 MWs each) in December 2023, 2025, and 2026, respectively, consistent with each unit's remaining useful life in the most recent approved depreciation studies. In addition, the schedule reflected the early retirement of Mississippi Power's 50% undivided ownership interest in Plant Daniel Units 1 and 2 (502 MWs) by the end of 2027. The Plant Greene County unit retirements require the completion by Alabama Power of transmission and system reliability improvements, as well as agreement by Alabama Power. The remaining net book value of Plant Daniel Units 1 and 2 was approximately $489 million at December 31, 2023 and Mississippi Power is continuing to depreciate these units using the current approved rates. Mississippi Power expects to reclassify the net book value remaining at retirement to a regulatory asset to be amortized over a period to be determined by the Mississippi PSC in future proceedings, consistent with the 2020 order. The Plant Watson and Greene County units are expected to be fully depreciated upon retirement. See Note 3 under "Other Matters – Mississippi Power" for additional information on Plant Daniel Units 1 and 2. In October 2023, Mississippi Power signed an affiliate PPA with Georgia Power for 750 MWs of capacity, which began January 1, 2024 and will continue through December 2028. In order to fulfill this PPA and serve the interests of customers, Mississippi Power now expects electric generating units identified in its 2021 IRP to remain in service beyond the previously indicated dates. Mississippi Power is expected to file its next IRP in April 2024 in accordance with the rules and orders of the Mississippi PSC. The ultimate outcome of these matters cannot be determined at this time. Environmental Compliance Overview Plan In accordance with a 2011 accounting order from the Mississippi PSC, Mississippi Power has the authority to defer in a regulatory asset for future recovery all plant retirement- or partial retirement-related costs resulting from environmental regulations. In June 2021, April 2022, and April 2023, the Mississippi PSC approved Mississippi Power's annual ECO Plan filings, resulting in a decrease in revenues of approximately $9 million annually effective with the first billing cycle of July 2021, an increase in revenues of approximately $1 million annually effective with the first billing cycle of May 2022, and a $3 million annual increase in revenues effective with the first billing cycle of May 2023, respectively. On February 12, 2024, Mississippi Power submitted its annual ECO Plan filing to the Mississippi PSC, which requested a $9 million annual increase in revenues. The ultimate outcome of this matter cannot be determined at this time. Fuel Cost Recovery Mississippi Power annually establishes, and is required to file for an adjustment to, the retail fuel cost recovery factor that is approved by the Mississippi PSC. The Mississippi PSC approved increases of $2 million and $43 million effective in February 2021 and 2022, respectively. In November 2022, Mississippi Power filed a request with the Mississippi PSC to increase retail fuel revenues by $25 million annually effective with the first billing cycle of February 2023 and an additional $25 million annually effective with the first billing cycle of June 2023. On January 10, 2023, the Mississippi PSC voted to defer approval of the filing. Mississippi Power is allowed to maintain current billing rates and continue accruing its weighted-average cost of capital on any under or over fuel recovery balance. On February 6, 2024, the Mississippi PSC approved Mississippi Power's request to increase retail fuel revenues by $18 million annually effective with the first billing cycle of March 2024. The approved filing included the deferral of approximately $61 million of under recovered fuel costs as of October 2023, which is expected to be included in Mississippi Power's next fuel filing. Mississippi Power will continue to accrue its weighted-average cost of capital on any under or over fuel recovery balance. At December 31, 2023, Mississippi Power had $50 million of deferred under recovered r etail fuel clause revenues and $27 million of over recovered retail fuel clause revenues primarily associated with its fuel-hedging program on its balance sheet. At December 31, 2022, under recovered retail fuel costs of approximately $1 million were included in other customer accounts receivable on Mississippi Power's balance sheet. See Note 1 under "Fuel Costs" for additional information. Mississippi Power has wholesale MRA and Market Based (MB) fuel cost recovery factors. Effective with the first billing cycles for January 2022, 2023, and 2024, annual revenues under the wholesale MRA fuel rate increased $11 million an d $22 million and decreased $4 million, re spectively. The wholesale MB fuel rate did not change materially in any period presented. At December 31, 2023 and 2022, wholesale fuel costs were over recovered $5 million and under recovered $6 million, respectively. Mississippi Power's operating revenues are adjusted for differences in actual recoverable fuel cost and amounts billed in accordance with the currently approved cost recovery rate. Accordingly, changes in the billing factor should have no significant effect on Mississippi Power's revenues or net income but will affect operating cash flows. Ad Valorem Tax Adjustment Mississippi Power annually establishes an ad valorem tax adjustment factor that is approved by the Mississippi PSC. Effective with the first billing cycle of May 2021, July 2022, and June 2023, the Mississippi PSC approved changes in annual revenues collected through the ad valorem tax adjustment factor resulting in a $28 million increase, a $5 million increase, and a $7 million decrease, respectively. The 2021 increase included approximately $19 million of ad valorem taxes previously recovered through PEP in accordance with a 2019 rate case settlement agreement. System Restoration Rider Mississippi Power carries insurance for the cost of certain types of damage to generation plants and general property. However, Mississippi Power is self-insured for the cost of storm, fire, and other uninsured casualty damage to its property, including transmission and distribution facilities. As permitted by the Mississippi PSC and the FERC, Mississippi Power accrues for the cost of such damage through an annual expense accrual which is credited to regulatory liability accounts for the retail and wholesale jurisdictions. The cost of repairing actual damage resulting from such events that individually exceed $50,000 is charged to the reserve. Every year, the Mississippi PSC, the MPUS, and Mississippi Power agree on SRR revenue level(s). Mississippi Power's net retail SRR accrual, which includes carrying costs and previously included amortization of related excess deferred income tax benefits, was $11.7 million in 2023, $6.9 million in 2022, and $(1.8) million in 2021. At December 31, 2023 and 2022, the retail property damage reserve balance was $45 million and $37 million, respectively. In 2021, the Mississippi PSC approved Mississippi Power's annual SRR filing, which requested an increase in retail revenues of approximately $9 million annually effective with the first billing cycle of March 2022. On April 4, 2023, th e Mississippi PSC approved Mississippi Power's annual SRR filing, which indicated no change in retail rates. Missi ssippi Power's minimum annual SRR accrual was increased from $8.3 million to $11.7 million. In the event the expected annual charges exceed the annual accrual or the target balance has been met, Mississippi Power and the Mississippi PSC will determine the appropriate change to the annual accrual. Additionally, if PEP earnings are above a certain threshold, Mississippi Power has the ability to apply any required PEP refund as an additional accrual to the property damage reserve in lieu of customer refunds. On February 1, 2024, Mississippi Power submitted its annual SRR filing to the Mississippi PSC, which indicated no change in retail rates. The filing includes a request to increase the minimum annual SRR accrual from $11.7 million to $12.6 million. Reliability Reserve Accounting Order In December 2022, the Mississippi PSC approved an accounting order authorizing Mississippi Power to create a reliability reserve for the purpose of deferring generation, transmission, and distribution reliability-related expenditures for use in a future year. Mississippi Power may make accruals to the reliability reserve each year after meeting with the MPUS and Mississippi PSC staff. Mississippi Power will provide annually, through its capital plan, energy delivery plan, or PEP filing, any amounts to be charged against the reliability reserve during the current year. During 2023 and 2022, Mississippi Power accrue d $11 million and $25 million, respectively, to the reliability reserve. At December 31, 2023 and 2022, the reliability reserve balance was $36 million and $25 million, respectively. Municipal and Rural Associations Tariff Mississippi Power provides wholesale electric service to Cooperative Energy, East Mississippi Electric Power Association, and the City of Collins, all located in southeastern Mississippi, under a long-term, cost-based, FERC-regulated MRA tariff. In 2017, Mississippi Power and Cooperative Energy executed, and the FERC accepted, a Shared Service Agreement (SSA), as part of the MRA tariff, under which Mississippi Power and Cooperative Energy share in providing electricity to the Cooperative Energy delivery points under the tariff. In August 2022, the FERC accepted an amended SSA between Mississippi Power and Cooperative Energy, effective July 1, 2022, under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At December 31, 2023, Mississippi Power is serving approximately 390 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On October 27, 2023, the FERC approved a settlement agreement filed by Mississippi Power and Cooperative Energy on July 31, 2023 related to Mississippi Power's July 2022 request for a $23 million increase in annual wholesale base revenues under the MRA tariff. The settlement agreement provides for a $16 million increase in annual wholesale base revenues, effective September 14, 2022, and a refund to customers of approximately $6 million primarily related to the difference between the approved rates and interim rates. Southern Company Gas Utility Regulation and Rate Design The natural gas distribution utilities are subject to regulation and oversight by their respective state regulatory agencies. Rates charged to customers vary according to customer class (residential, commercial, or industrial) and rate jurisdiction. These agencies approve rates designed to provide the opportunity to generate revenues to recover all prudently-incurred costs, including a return on rate base sufficient to pay interest on debt and provide a reasonable ROE. As a result of operating in a deregulated environment, Atlanta Gas Light earns revenue by charging rates to its customers based primarily on monthly fixed charges that are set by the Georgia PSC and adjusted periodically. The Marketers add these fixed charges when billing their respective customers. This mechanism, called a straight-fixed-variable rate design, minimizes the seasonality of Atlanta Gas Light's revenues since the monthly fixed charge is not volumetric or directly weather dependent. With the exception of Atlanta Gas Light, the earnings of the natural gas distribution utilities can be affected by customer consumption patterns that are largely a function of weather conditions and price levels for natural gas. Specifically, customer demand substantially increases during the Heating Season when natural gas is used for heating purposes. Southern Company Gas has various mechanisms, such as weather and revenue normalization mechanisms and weather derivative instruments, that limit exposure to weather changes within typical ranges in these utilities' respective service territories. In addition to natural gas cost recovery mechanisms, other cost recovery mechanisms and regulatory riders, which vary by utility, allow recovery of certain costs, such as those related to infrastructure replacement programs as well as environmental remediation, energy efficiency plans, and bad debts. In traditional rate designs, utilities recover a significant portion of the fixed customer service and pipeline infrastructure costs based on assumed natural gas volumes used by customers. With the exception of Chattanooga Gas, the natural gas distribution utilities have decoupled regulatory mechanisms that Southern Company Gas believes encourage conservation by separating the recoverable amount of these fixed costs from the amounts of natural gas used by customers. See "Rate Proceedings" herein for additional information. Also see "Infrastructure Replacement Programs and Capital Projects" herein for additional information regarding infrastructure replacement programs at certain of the natural gas distribution utilities. The following table provides regulatory information for Southern Company Gas' natural gas distribution utilities:
| Nicor Gas |  | Atlanta Gas Light |  | Virginia Natural Gas |  | Chattanooga Gas
Authorized ROE at December 31, 2023 | 9.51% |  | 10.25% |  | 9.70% |  | 9.80%
Weather normalization mechanisms(a) |  |  |  |  | ü |  | ü
Decoupled, including straight-fixed-variable rates(b) | ü |  | ü |  | ü |  |
Regulatory infrastructure program rate(c) | ü |  | ü |  | ü |  | ü
Bad debt rider(d) | ü |  |  |  | ü |  | ü
Energy efficiency plan(e) | ü |  |  |  | ü |  |
Annual base rate adjustment mechanism(f) |  |  | ü |  |  |  | ü
Year of last base rate case decision | 2023 |  | 2019 |  | 2023 |  | 2018
(a)Designed to help stabilize operating results by allowing recovery of costs in the event of unseasonal weather, but are not direct offsets to the potential impacts on earnings of weather and customer consumption. (b)Allows for recovery of fixed customer service costs separately from assumed natural gas volumes used by customers and provides a benchmark level of revenue for recovery. (c)See "Infrastructure Replacement Programs and Capital Projects" herein for additional information. Chattanooga Gas' pipeline replacement program costs are recovered through its annual base rate review mechanism. (d)The recovery (refund) of bad debt expense over (under) an established benchmark expense. The gas portion of bad debt expense is recovered through purchased gas adjustment mechanisms. Nicor Gas also has a rider to recover the non-gas portion of bad debt expense. (e)Recovery of costs associated with plans to achieve specified energy savings goals. (f)Regulatory mechanism allowing annual adjustments to base rates up or down based on authorized ROE and/or ROE range. Infrastructure Replacement Programs and Capital Projects In addition to capital expenditures recovered through base rates by each of the natural gas distribution utilities, Nicor Gas and Virginia Natural Gas have separate rate riders that provide timely recovery of capital expenditures for specific infrastructure replacement programs and Atlanta Gas Light has a separate rate rider that provides for the timely recovery of capital expenditures for a specific reinforcement capital program. Total capital expenditures incurred during 2023 for all gas distribution operations were $1.6 billion. The following table and discussions provide updates on the infrastructure replacement programs and capital projects at the natural gas distribution utilities at December 31, 2023. These programs are risk-based and designed to update and replace cast iron, bare steel, and mid-vintage plastic materials or expand Southern Company Gas' distribution systems to improve reliability and meet operational flexibility and growth.
Utility |  | Program |  | Recovery |  | Capital Expenditures in 2023 |  | Capital Expenditures Since Project Inception |  | Pipe Installed Since Project Inception |  | Scope of Program |  | Program Duration |  | Last Year of Program
|  |  |  |  |  | (in millions) |  | (miles) |  | (miles) |  | (years) |  |
Nicor Gas |  | Investing in Illinois Qualifying Infrastructure Plant(*) |  | Rider |  | $ 365 |  | $ 3,228 |  | 1,367 |  | 1,367 |  | 9 |  | 2023
Virginia Natural Gas |  | SAVE |  | Rider |  | 75 |  | 486 |  | 567 |  | 695 |  | 13 |  | 2024
Atlanta Gas Light |  | System Reinforcement Rider |  | Rider |  | 104 |  | 180 |  | 20 |  | N/A |  | 3 |  | 2024
Chattanooga Gas |  | Pipeline Replacement Program |  | Rate Base |  | 9 |  | 16 |  | 15 |  | 73 |  | 7 |  | 2027
Total |  |  |  |  |  | $ 553 |  | $ 3,910 |  | 1,969 |  | 2,135 |  |  |  |
*Included replacement of pipes, compressors, and transmission mains along with other improvements such as new meters. This program ended November 30, 2023 with all expenditures placed in service. Recovery of program costs is described under "Nicor Gas" herein. Nicor Gas Illinois legislation allows Nicor Gas to provide more widespread safety and reliability enhancements to its distribution system through 2023 and stipulates that rate increases to customers as a result of any infrastructure investments shall not exceed a cumulative annual average of 4.0% or, in any given year, 5.5% of base rate revenues. In 2014, the Illinois Commission approved the nine-year regulatory infrastructure program, Investing in Illinois, which concluded in 2023 and is subject to annual review, as discussed further below. In accordance with orders from the Illinois Commission, Nicor Gas recovers program costs incurred through a separate rider and base rates. See "Rate Proceedings – Nicor Gas" herein for additional information. On June 15, 2023, the Illinois Commission concluded its review of the Qualifying Infrastructure Plant (QIP) capital investments by Nicor Gas for calendar year 2019 under the QIP rider, also referred to as Investing in Illinois program. The Illinois Commission disallowed $32 million of the $415 million of capital investments commissioned in 2019, together with the related return on investment. Nicor Gas recorded a pre-tax charge to income in the second quarter 2023 of $38 million ($28 million after tax) associated with the disallowance of capital investments placed in service in 2019. The disallowance is reflected on the statement of income as an $8 million reduction to revenues and $30 million in estimated loss on regulatory disallowance. On August 3, 2023, the Illinois Commission denied a rehearing request filed by Nicor Gas. On August 24, 2023, Nicor Gas filed a notice of appeal with the Illinois Appellate Court. Nicor Gas defends these investments in infrastructure as prudently incurred. The following table provides a summary of QIP capital investments during the nine-year program:
Year | Status of QIP Annual Review Proceeding | Capital Investments |  | Disallowed |  | Month of Disallowance
|  | (in millions) |  |
2015 – 2018 | Complete | $ 1,246 |  | $ — |  |
2019 | Complete(a) | 415 |  | 32 |  | June 2023
2020 | Filed March 2021 | 402 | (b) |  |  |
2021 | Filed March 2022 | 392 | (b) |  |  |
2022 | Filed March 2023 | 408 | (b) | 6 | (a)(c) | November 2023
2023 | To be filed by March 20, 2024 | 365 | (b) | 25 | (a)(c) | November 2023
| $ 3,228 |  | $ 63 |  |
(a)Appealed to the Illinois Appellate Court. (b)Capital investments are subject to the required QIP annual review proceeding; years 2020 through 2022 are pending with the Illinois Commission. (c)Disallowed in Nicor Gas' 2023 general base rate case proceeding. See "Rate Proceedings – Nicor Gas" herein for additional information regarding the Illinois Commission's disallowance of certain capital investments. Any further cost disallowances by the Illinois Commission in the pending cases could be material to the financial statements of Southern Company Gas. The ultimate outcome of these matters cannot be determined at this time. Virginia Natural Gas The SAVE program, an accelerated infrastructure replacement program, allows Virginia Natural Gas to continue replacing aging pipeline infrastructure through 2024. The program includes authorized annual investments of $60 million in 2021 and $70 million in each year from 2022 through 2024, with a total potential variance of up to $5 million allowed for the program, for a maximum total investment over the six-year term (2019 through 2024) of $365 million. O n February 9, 2024, Virginia Natural Gas filed with the Virginia Commission a request to extend the existing SAVE program through 2029. The request includes investments of $70 million in each year from 2025 through 2029, with a potential variance of up to $5 million allowed for the program, for a maximum total investment over the five-year extension (2025 through 2029) of $355 million. Virginia Natural Gas expects the Virginia Commission to issue a final order on this matter in the second quarter 2024. The ultimate outcome of this matter cannot be determined at this time. The SAVE program is subject to annual review by the Virginia Commission. In accordance with the base rate case approved by the Virginia Commission in 2023, Virginia Natural Gas is recovering program costs incurred prior to January 1, 2023 through base rates. Program costs incurred subsequent to January 1, 2023 are currently being recovered through a separate rider and are subject to future base rate case proceedings. See "Rate Proceedings – Virginia Natural Gas" herein for additional information. Atlanta Gas Light In 2019, the Georgia PSC approved the continuation of GRAM as part of Atlanta Gas Light's 2019 rate case order. Various infrastructure programs previously authorized by the Georgia PSC, including the Integrated Vintage Plastic Replacement Program to replace aging plastic pipe and the Integrated System Reinforcement Program to upgrade Atlanta Gas Light's distribution system and LNG facilities in Georgia, continue under GRAM and the recovery of and return on the infrastructure program investments are included in annual base rate adjustments. The amounts to be recovered through rates related to allowed, but not incurred, costs have been quantified as an unrecognized ratemaking amount that is not reflected on the balance sheets. These allowed costs are primarily the equity return on the capital investment under the infrastructure programs in place prior to GRAM and are being recovered through GRAM and base rates until the earlier of the full recovery of such amounts or December 31, 2025. The under recovered balance at December 31, 2023 was $44 million, including $23 million of unrecognized equity return, and is expected to be recovered by December 31, 2025. The Georgia PSC reviews Atlanta Gas Light's performance annually under GRAM. See "Unrecognized Ratemaking Amounts" herein for additional information. Atlanta Gas Light and the staff of the Georgia PSC previously agreed to a variation of the Integrated Customer Growth Program to extend pipeline facilities to serve customers in areas without pipeline access and create new economic development opportunities in Georgia. A separate tariff provides recovery of up to $15 million annually for strategic economic development projects approved by the Georgia PSC. See "Rate Proceedings – Atlanta Gas Light" herein for additional information regarding the Georgia PSC's 2021 approval of Atlanta Gas Light's GRAM filing and Integrated Capacity and Delivery Plan. The Georgia PSC also approved a new System Reinforcement Rider for authorized large pressure improvement and system reliability projects, which is expected to recover related capital investments totaling $286 million for the years 2022 through 2024, of which $104 million and $76 million was incurred in 2023 and 2022, respectively. Chattanooga Gas In 2021, the Tennessee Public Utilities Commission approved Chattanooga Gas' pipeline replacement program to replace approximately 73 miles of distribution main over a seven-year period. The estimated total cost of the program is $118 million, which will be recovered through Chattanooga Gas' annual base rate review mechanism. Natural Gas Cost Recovery With the exception of Atlanta Gas Light, the natural gas distribution utilities are authorized by the relevant regulatory agencies in the states in which they serve to use natural gas cost recovery mechanisms that adjust rates to reflect changes in the wholesale cost of natural gas and ensure recovery of all costs prudently incurred in purchasing natural gas for customers. The natural gas distribution utilities defer or accrue the difference between the actual cost of natural gas and the amount of commodity revenue earned in a given period. The deferred or accrued amount is either billed or refunded to customers prospectively through adjustments to the commodity rate. Deferred natural gas costs are reflected as regulatory assets and accrued natural gas costs are reflected as regulatory liabilities. Natural gas costs generally do not have a significant effect on Southern Company's or Southern Company Gas' net income, but could have a significant effect on cash flows. Since Atlanta Gas Light does not sell natural gas directly to its end-use customers, it does not utilize a traditional natural gas cost recovery mechanism. However, Atlanta Gas Light does maintain natural gas inventory for the Marketers in Georgia and recovers the cost through recovery mechanisms approved by the Georgia PSC. At December 31, 2023, the over recovered balance was $214 million, which was included in natural gas cost over recovery on Southern Company's and Southern Company Gas' balance sheets. At December 31, 2022, the under recovered balance was $108 million, which was included in natural gas cost under recovery on Southern Company's and Southern Company Gas' balance sheets. Rate Proceedings Nicor Gas In 2021, the Illinois Commission approved a $240 million annual base rate increase, which became effective November 24, 2021. The base rate increase included $94 million related to the recovery of program costs under the Investing in Illinois program and was based on a ROE of 9.75% and an equity ratio of 54.5%. On November 16, 2023, the Illinois Commission approved a $223 million annual base rate increase for Nicor Gas, which became effe ctive December 1, 2023. The base rate increase was based on a return on equity of 9.51% and an equity ratio of 50.00%. In connection with Nicor Gas' general base rate case proceeding, the Illinois Commission disallowed $126.8 million of capital investments that have been completed or planned to be completed through December 31, 2024. This includes $31 million for capital investments placed in service in 2022 and 2023 under the Investing in Illinois program and $95.9 million for other transmission and distribution capital investments. Nicor Gas recorded a pre-tax charge to income in the fourth quarter 2023 of $58 million ($44 million after tax) associated with the disallowances, with the remaining $69 million related to prospective projects that will be postponed and/or reevaluated. The disallowance is reflected on the statement of income in estimated loss on regulatory disallowance. See "Infrastructure Replacement Programs and Capital Projects – Nicor Gas" herein for additional information regarding the Illinois Commission's disallowance of certain capital investments. On January 3, 2024, the Illinois Commission denied a request by Nicor Gas for rehearing on the base rate case disallowances associated with capital investment, as well as on other issues determined in the Illinois Commission's November 16, 2023 base rate case decision. On February 6, 2024, Nicor Gas filed a notice of appeal with the Illinois Appellate Court related to the Illinois Commission's rate case ruling. The ultimate outcome of this matter cannot be determined at this time. Atlanta Gas Light The Georgia PSC evaluates Atlanta Gas Light's earnings against a ROE range of 10.05% to 10.45%, with disposition of any earnings above 10.45% to be determined by the Georgia PSC. Additionally, the Georgia PSC allows inclusion in base rates of the recovery of and return on the infrastructure program investments, including, but not limited to, GRAM adjustments. GRAM filing rate adjustments are based on an authorized ROE of 10.25%. GRAM adjustments for 2021 could not exceed 5% of 2020 base rates. The 5% limitation does not set a precedent in any future rate proceedings by Atlanta Gas Light. In April 2021, Atlanta Gas Light filed its Integrated Capacity and Delivery Plan (i-CDP) with the Georgia PSC, which included a series of ongoing and proposed pipeline safety, reliability, and growth programs for the next 10 years (2022 through 2031), as well as the required capital investments and related costs to implement the programs. The i-CDP reflected capital investments totaling approximately $0.5 billion to $0.6 billion annually. In November 2021, the Georgia PSC approved a stipulation agreement between Atlanta Gas Light and the staff of the Georgia PSC, under which, for the years 2022 through 2024, Atlanta Gas Light will incrementally reduce its combined GRAM and System Reinforcement Rider request by 10% through Atlanta Gas Light's GRAM mechanism, which resulted in a reduction of $5 million for 2022, $7 million for 2023, and $9 million for 2024. The stipulation agreement also provided for $1.7 billion of total capital investment for the years 2022 through 2024. In November 2021, December 2022, and December 2023, the Georgia PSC approved Atlanta Gas Light's annual GRAM filings, which resulted in an annual rate increase of $43 million effective January 1, 2022, an annual rate increase of $53 million effective January 1, 2023, and an annual rate increase of $53 million effective January 1, 2024, respectively. On February 1, 2024, Atlanta Gas Light filed its triennial i-CDP with the Georgia PSC, which included a series of ongoing and proposed pipeline safety, reliability, and growth programs for the next 10 years (2025 through 2034), as well as the required capital investments and related costs to implement the programs. The i-CDP reflected capital investments totaling approximately $0.7 billion to $1.0 billion annually. Atlanta Gas Light expects the Georgia PSC to issue a final order on this matter in the third quarter 2024. The ultimate outcome of this matter cannot be determined at this time. Virginia Natural Gas In 2021, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas' 2020 general rate case filing, which allowed for a $43 million increase in annual base rate revenues, including $14 million related to the recovery of investments under the SAVE program, based on a ROE of 9.5% and an equity ratio of 51.9%. Interim rates became effective as of November 1, 2020, subject to refund, based on Virginia Natural Gas' original requested increase of approximately $50 million. Refunds to customers related to the difference between the approved rates effective October 1, 2021 and the interim rates were completed during the fourth quarter 2021. On August 28, 2023, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas' August 2022 general base rate case filing, which allowed for a $48 million increase in annual base rate revenues based on a ROE of 9.70% and an equity ratio of 49.06%. Interim rates became effective as of January 1, 2023, subject to refund, based on Virginia Natural Gas' original requested increase of approximately $69 million. Refunds to customers related to the difference between the approved rates effective September 1, 2023 and the interim rates were completed during the fourth quarter 2023. Unrecognized Ratemaking Amounts The following table illustrates Southern Company Gas' authorized ratemaking amounts that are not recognized on its balance sheets. These amounts are primarily comprised of an allowed equity rate of return on assets associated with certain regulatory infrastructure programs. These amounts will be recognized as revenues in Southern Company Gas' financial statements in the periods they are billable to customers, the majority of which will be recovered by 2025.
| December 31, 2023 |  | December 31, 2022
| (in millions)
Atlanta Gas Light | $ 23 |  | $ 35
Virginia Natural Gas | 10 |  | 10
Chattanooga Gas | 7 |  | 2
Nicor Gas | 3 |  | 3
Total | $ 43 |  | $ 50
4. REVENUE FROM CONTRACTS WITH CUSTOMERS The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 under "Revenues" for additional information on the revenue policies of the Registrants. See Notes 9 and 14 for additional information on revenue accounted for under lease and derivative accounting guidance, respectively. The following table disaggregates revenue from contracts with customers for the periods presented:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |  |
Operating revenues |  |  |  |  |  |
Retail electric revenues |  |  |  |  |  |
Residential | $ 7,309 | $ 2,904 | $ 4,105 | $ 300 | $ — | $ —
Commercial | 5,860 | 1,928 | 3,624 | 308 | — | —
Industrial | 3,613 | 1,721 | 1,558 | 334 | — | —
Other | 112 | 12 | 91 | 9 | — | —
Total retail electric revenues | 16,894 | 6,565 | 9,378 | 951 | — | —
Natural gas distribution revenues |  |  |  |  |  |
Residential | 1,981 | — | — | — | — | 1,981
Commercial | 505 | — | — | — | — | 505
Transportation | 1,184 | — | — | — | — | 1,184
Industrial | 45 | — | — | — | — | 45
Other | 324 | — | — | — | — | 324
Total natural gas distribution revenues | 4,039 | — | — | — | — | 4,039
Wholesale electric revenues |  |  |  |  |  |
PPA energy revenues | 1,107 | 234 | 87 | 20 | 790 | —
PPA capacity revenues | 624 | 156 | 51 | 45 | 376 | —
Non-PPA revenues | 250 | 65 | 35 | 407 | 409 | —
Total wholesale electric revenues | 1,981 | 455 | 173 | 472 | 1,575 | —
Other natural gas revenues |  |  |  |  |  |
Gas marketing services | 528 | — | — | — | — | 528
Other natural gas revenues | 31 | — | — | — | — | 31
Total natural gas revenues | 559 | — | — | — | — | 559
Other revenues | 1,355 | 213 | 578 | 39 | 55 | —
Total revenue from contracts with customers | 24,828 | 7,233 | 10,129 | 1,462 | 1,630 | 4,598
Other revenue sources(a) | 425 | (183) | (11) | 12 | 559 | 104
Total operating revenues | $ 25,253 | $ 7,050 | $ 10,118 | $ 1,474 | $ 2,189 | $ 4,702
2022 |  |  |  |  |  |
Operating revenues |  |  |  |  |  |
Retail electric revenues |  |  |  |  |  |
Residential | $ 6,604 | $ 2,638 | $ 3,664 | $ 302 | $ — | $ —
Commercial | 5,369 | 1,685 | 3,385 | 299 | — | —
Industrial | 3,764 | 1,507 | 1,921 | 336 | — | —
Other | 102 | 14 | 79 | 9 | — | —
Total retail electric revenues | 15,839 | 5,844 | 9,049 | 946 | — | —
Natural gas distribution revenues |  |  |  |  |  |
Residential | 2,843 | — | — | — | — | 2,843
Commercial | 763 | — | — | — | — | 763
Transportation | 1,186 | — | — | — | — | 1,186
Industrial | 84 | — | — | — | — | 84
Other | 342 | — | — | — | — | 342
Total natural gas distribution revenues | 5,218 | — | — | — | — | 5,218
Wholesale electric revenues |  |  |  |  |  |
PPA energy revenues | 2,274 | 489 | 130 | 16 | 1,673 | —
PPA capacity revenues | 596 | 194 | 47 | 4 | 356 | —
Non-PPA revenues | 250 | 200 | 30 | 690 | 740 | —
Total wholesale electric revenues | 3,120 | 883 | 207 | 710 | 2,769 | —
Other natural gas revenues |  |  |  |  |  |
Gas marketing services | 636 | — | — | — | — | 636
Other natural gas revenues | 51 | — | — | — | — | 51
Total other natural gas revenues | 687 | — | — | — | — | 687
Other revenues | 1,077 | 194 | 446 | 47 | 36 | —
Total revenue from contracts with customers | 25,941 | 6,921 | 9,702 | 1,703 | 2,805 | 5,905
Other revenue sources(a) | 3,338 | 896 | 1,882 | (9) | 564 | 57
Total operating revenues | $ 29,279 | $ 7,817 | $ 11,584 | $ 1,694 | $ 3,369 | $ 5,962
2021 |  |  |  |  |  |
Operating revenues |  |  |  |  |  |
Retail electric revenues |  |  |  |  |  |
Residential | $ 6,207 | $ 2,467 | $ 3,471 | $ 269 | $ — | $ —
Commercial | 4,877 | 1,600 | 3,010 | 267 | — | —
Industrial | 3,067 | 1,386 | 1,391 | 290 | — | —
Other | 93 | 17 | 68 | 8 | — | —
Total retail electric revenues | 14,244 | 5,470 | 7,940 | 834 | — | —
Natural gas distribution revenues |  |  |  |  |  |
Residential | 1,799 | — | — | — | — | 1,799
Commercial | 470 | — | — | — | — | 470
Transportation | 1,038 | — | — | — | — | 1,038
Industrial | 49 | — | — | — | — | 49
Other | 269 | — | — | — | — | 269
Total natural gas distribution revenues | 3,625 | — | — | — | — | 3,625
Wholesale electric revenues |  |  |  |  |  |
PPA energy revenues | 1,122 | 184 | 95 | 11 | 854 | —
PPA capacity revenues | 493 | 115 | 55 | 5 | 323 | —
Non-PPA revenues | 236 | 170 | 21 | 401 | 398 | —
Total wholesale electric revenues | 1,851 | 469 | 171 | 417 | 1,575 | —
Other natural gas revenues |  |  |  |  |  |
Wholesale gas services | 2,168 | — | — | — | — | 2,168
Gas marketing services | 464 | — | — | — | — | 464
Other natural gas revenues | 36 | — | — | — | — | 36
Total other natural gas revenues | 2,668 | — | — | — | — | 2,668
Other revenues | 1,075 | 202 | 452 | 31 | 30 | —
Total revenue from contracts with customers | 23,463 | 6,141 | 8,563 | 1,282 | 1,605 | 6,293
Other revenue sources(a) | 3,349 | 272 | 697 | 40 | 611 | 1,786
Other adjustments(b) | (3,699) | — | — | — | — | (3,699)
Total operating revenues | $ 23,113 | $ 6,413 | $ 9,260 | $ 1,322 | $ 2,216 | $ 4,380
(a)Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas, and cost recovery mechanisms and revenues (including those related to fuel costs) that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies. (b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Notes 15 and 16 under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively. Contract Balances The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at December 31, 2023 and 2022:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Accounts Receivable |  |  |  |  |  |
At December 31, 2023 | $ 2,820 | $ 821 | $ 1,011 | $ 90 | $ 122 | $ 684
At December 31, 2022 | 3,123 | 696 | 922 | 92 | 237 | 1,107
Contract Assets |  |  |  |  |  |
At December 31, 2023 | $ 271 | $ 2 | $ 121 | $ — | $ — | $ 56
At December 31, 2022 | 156 | 2 | 89 | — | — | —
Contract Liabilities |  |  |  |  |  |
At December 31, 2023 | $ 116 | $ — | $ 1 | $ — | $ 4 | $ —
At December 31, 2022 | 45 | 4 | 9 | — | 1 | —
Contract assets for Georgia Power primarily relate to retail customer fixed bill programs, where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over a one-year contract term, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power primarily relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company Gas' contract assets relate to work performed on an energy efficiency enhancement and upgrade contract with the U.S. General Services Administration. Southern Company Gas receives cash advances from a third-party financial institution to fund work performed, of which approximately $59 million had been received at December 31, 2023. These advances have been accounted for as long-term debt on the balance sheets. See Note 1 under "Affiliate Transactions" for additional information regarding the construction contract. At December 31, 2023 and 2022, Southern Company's unregulated distributed generation business had contract assets of $91 million and $65 million, respectively, and contract liabilities of $115 million and $32 million, respectively, for outstanding performance obligations. Revenues recognized in 2023 and 2022, which were included in contract liabilities at December 31, 2023 and 2022, respectively, were $36 million annually for Southern Company and immaterial for the other Registrants. Contract liabilities are primarily classified as current on the balance sheets as the corresponding revenues are generally expected to be recognized within one year. Remaining Performance Obligations The Subsidiary Registrants may enter into long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to PPAs whereby electricity and generation capacity are provided to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. For Southern Company Gas, these contracts primarily relate to the U.S. General Services Administration contract described above. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at December 31, 2023 are expected to be recognized as follows:
| 2024 | 2025 | 2026 | 2027 | 2028 | Thereafter
| (in millions)
Southern Company | $ 940 | $ 552 | $ 338 | $ 332 | $ 323 | $ 2,045
Alabama Power | 23 | 9 | — | — | — | —
Georgia Power | 73 | 41 | 14 | 15 | 15 | 9
Mississippi Power | 60 | 63 | 66 | 69 | 73 | —
Southern Power | 379 | 301 | 299 | 306 | 297 | 2,041
Southern Company Gas | 26 | — | — | — | — | —
5. PROPERTY, PLANT, AND EQUIPMENT Property, plant, and equipment is stated at original cost or fair value at acquisition, as appropriate, less any regulatory disallowances and impairments. Original cost may include: materials; labor; minor items of property; appropriate administrative and general costs; payroll-related costs such as taxes, pensions, and other benefits; and the interest capitalized and/or cost of equity funds used during construction. The Registrants' property, plant, and equipment in service consisted of the following at December 31, 2023 and 2022:
At December 31, 2023: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Electric utilities: |  |  |  |  |  |
Generation | $ 57,325 | $ 16,584 | $ 22,587 | $ 2,909 | $ 14,649 | $ —
Transmission | 15,561 | 6,152 | 8,402 | 966 | — | —
Distribution | 26,482 | 9,775 | 15,380 | 1,327 | — | —
General/other | 6,305 | 2,918 | 3,001 | 321 | 41 | —
Electric utilities' plant in service | 105,673 | 35,429 | 49,370 | 5,523 | 14,690 | —
Southern Company Gas: |  |  |  |  |  |
Natural gas transportation and distribution | 17,798 | — | — | — | — | 17,798
Storage facilities | 1,565 | — | — | — | — | 1,565
Other | 1,477 | — | — | — | — | 1,477
Southern Company Gas plant in service | 20,840 | — | — | — | — | 20,840
Other plant in service | 1,915 | — | — | — | — | —
Total plant in service | $ 128,428 | $ 35,429 | $ 49,370 | $ 5,523 | $ 14,690 | $ 20,840
At December 31, 2022: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Electric utilities: |  |  |  |  |  |
Generation | $ 51,756 | $ 15,920 | $ 17,755 | $ 2,826 | $ 14,619 | $ —
Transmission | 14,201 | 5,658 | 7,576 | 927 | — | —
Distribution | 24,200 | 9,154 | 13,819 | 1,228 | — | —
General/other | 5,806 | 2,740 | 2,729 | 273 | 39 | —
Electric utilities' plant in service | 95,963 | 33,472 | 41,879 | 5,254 | 14,658 | —
Southern Company Gas: |  |  |  |  |  |
Natural gas transportation and distribution | 16,810 | — | — | — | — | 16,810
Storage facilities | 1,553 | — | — | — | — | 1,553
Other | 1,360 | — | — | — | — | 1,360
Southern Company Gas plant in service | 19,723 | — | — | — | — | 19,723
Other plant in service | 1,843 | — | — | — | — | —
Total plant in service | $ 117,529 | $ 33,472 | $ 41,879 | $ 5,254 | $ 14,658 | $ 19,723
The cost of replacements of property, exclusive of minor items of property, is capitalized. The cost of maintenance, repairs, and replacement of minor items of property is charged to other operations and maintenance expenses as incurred or performed with the exception of nuclear refueling costs and certain maintenance costs including those described below. In accordance with orders from their respective state PSCs, Alabama Power and Georgia Power defer nuclear refueling outage operations and maintenance expenses to a regulatory asset when the charges are incurred. Alabama Power amortizes the costs over a subsequent 18-month period with Plant Farley's fall outage cost amortization beginning in January of the following year and spring outage cost amortization beginning in July of the same year. Georgia Power amortizes its costs over each unit's operating cycle, or 18 months for Plant Vogtle Units 1, 2, and 3 and 24 months for Plant Hatch Units 1 and 2. Georgia Power's amortization period begins the month the refueling outage starts. A portion of Mississippi Power's railway track maintenance costs is charged to fuel stock and recovered through Mississippi Power's fuel clause. The portion of Southern Company Gas' non-working gas used to maintain the structural integrity of natural gas storage facilities that is considered to be non-recoverable is depreciated, while the recoverable or retained portion is not depreciated. See Note 9 for information on finance lease right-of-use (ROU) assets, net, which are included in property, plant, and equipment. The Registrants have deferred certain implementation costs related to cloud hosting arrangements. At December 31, 2023 and 2022, deferred cloud implementation costs, net of amortization, which are generally included in other deferred charges and assets on the Registrants' balance sheets, are as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Deferred cloud implementation costs, net: |  |  |  |  |  |
At December 31, 2023 | $ 325 | $ 85 | $ 99 | $ 13 | $ 15 | $ 43
At December 31, 2022 | 345 | 81 | 108 | 14 | 18 | 54
Once a hosted software is placed into service, the related deferred costs are amortized on a straight-line basis over the remaining expected hosting arrangement term, including any renewal options that are reasonably certain of exercise. The amortization is reflected with the associated cloud hosting fees, which are generally reflected in other operations and maintenance expenses on the Registrants' statements of income. In 2023, amortization of deferred cloud implementation costs recognized was $46 million for Southern Company, $11 million for Alabama Power, $19 million for Georgia Power, $8 million for Southern Company Gas, and immaterial for the other Registrants. In 2022, amortization of deferred cloud implementation costs recognized was $29 million for Southern Company, $8 million for Alabama Power, $12 million for Georgia Power, and immaterial for the other Registrants. In 2021, amortization from deferred cloud implementation costs recognized was immaterial for all Registrants. See Note 2 under "Regulatory Assets and Liabilities" and "Alabama Power – Software Accounting Order" for information on deferrals of certain other operations and maintenance costs associated with software and cloud computing projects by the traditional electric operating companies and natural gas distribution utilities, as authorized by their respective state PSCs or applicable state regulatory agencies. Depreciation and Amortization The traditional electric operating companies' and Southern Company Gas' depreciation of the original cost of utility plant in service is provided primarily by using composite straight-line rates. The approximate rates for 2023, 2022, and 2021 are as follows:
| 2023 | 2022 | 2021
Alabama Power | 4.1 % | 2.7 % | 2.7 %
Georgia Power | 3.8 % | 3.3 % | 3.3 %
Mississippi Power | 3.4 % | 3.4 % | 3.6 %
Southern Company Gas | 2.7 % | 2.7 % | 2.8 %
Depreciation studies are conducted periodically to update the composite rates. These studies are filed with the respective state PSC and/or other applicable state and federal regulatory agencies for the traditional electric operating companies and the natural gas distribution utilities. Effective January 1, 2023, Alabama Power's and Georgia Power's depreciation rates were revised. See Note 2 for additional information. When property, plant, and equipment subject to composite depreciation is retired or otherwise disposed of in the normal course of business, its original cost, together with the cost of removal, less salvage, is charged to accumulated depreciation. For other property dispositions, the applicable cost and accumulated depreciation are removed from the balance sheet accounts, and a gain or loss is recognized. Minor items of property included in the original cost of the asset are retired when the related property unit is retired. At December 31, 2023 and 2022, accumulated depreciation for Southern Company and Southern Company Gas consisted of utility plant in service totaling $36.6 billion and $34.3 billion, respectively, for Southern Company and $5.3 billion and $5.1 billion, respectively, for Southern Company Gas, as well as other plant in service totaling $1.1 billion and $1.0 billion, respectively, for Southern Company and $210 million and $184 million, respectively, for Southern Company Gas. Other plant in service includes the non-utility assets of Southern Company Gas, as well as, for Southern Company, certain other non-utility subsidiaries. Depreciation of the original cost of other plant in service is provided primarily on a straight-line basis over estimated useful lives. Useful lives for Southern Company Gas's non-utility assets range from five to 12 years for transportation equipment, 30 to 75 years for storage facilities, and up to 75 years for other assets. Useful lives for the assets of Southern Company's other non-utility subsidiaries range up to 30 years. Southern Power Southern Power applies component depreciation, where depreciation is computed principally by the straight-line method over the estimated useful life of the asset. Certain of Southern Power's generation assets related to natural gas-fired facilities are depreciated on a units-of-production basis, using hours or starts, to better match outage and maintenance costs to the usage of, and revenues from, these assets. The primary assets in Southern Power's property, plant, and equipment are generating facilities, which generally have estimated useful lives as follows:
Southern Power Generating Facility | Useful life
Natural gas | Up to 50 years
Solar | Up to 35 years
Wind | Up to 35 years
When Southern Power's depreciable property, plant, and equipment is retired, or otherwise disposed of in the normal course of business, the applicable cost and accumulated depreciation is removed and a gain or loss is recognized in the statements of income. Southern Power reviews its estimated useful lives and salvage values on an ongoing basis. The results of these reviews could result in changes which could have a material impact on Southern Power's net income. Joint Ownership Agreements At December 31, 2023, the Registrants' percentage ownership and investment (exclusive of nuclear fuel) in jointly-owned facilities in commercial operation were as follows:
Facility (Type) | Percent Ownership |  | Plant in Service |  | Accumulated Depreciation |  | CWIP
|  |  | (in millions)
Alabama Power |  |  |  |  |  |  |
Greene County (natural gas) Units 1 and 2 | 60.0 % | (a) | $ 191 |  | $ 113 |  | $ 1
Plant Miller (coal) Units 1 and 2 | 91.8 | (b) | 2,156 |  | 778 |  | 40
Georgia Power |  |  |  |  |  |  |
Plant Hatch (nuclear) Units 1 and 2 | 50.1 % | (c) | $ 1,446 |  | $ 659 |  | $ 70
Plant Vogtle (nuclear) Units 1 and 2 | 45.7 | (c) | 3,664 |  | 2,331 |  | 62
Plant Vogtle (nuclear) Units 3 and 4 | 45.7 | (c)(d) | 4,613 |  | 19 |  | 3,232
Plant Scherer (coal) Units 1 and 2 | 8.4 | (c) | 287 |  | 123 |  | 2
Plant Scherer (coal) Unit 3 | 75.0 | (c) | 1,310 |  | 639 |  | 10
Rocky Mountain (pumped storage) | 25.4 | (e) | 181 |  | 153 |  | —
Mississippi Power |  |  |  |  |  |  |
Greene County (natural gas) Units 1 and 2 | 40.0 % | (a) | $ 125 |  | $ 80 |  | $ —
Plant Daniel (coal) Units 1 and 2 | 50.0 | (f) | 805 |  | 281 |  | 1
Southern Company Gas |  |  |  |  |  |  |
Dalton Pipeline (natural gas pipeline) | 50.0 % | (g) | $ 271 |  | $ 27 |  | $ —
(a)Jointly owned by Alabama Power and Mississippi Power and operated and maintained by Alabama Power. (b)Jointly owned with PowerSouth and operated and maintained by Alabama Power. (c)Georgia Power owns undivided interests in Plants Hatch, Vogtle, and Scherer in varying amounts jointly with one or more of the following entities: OPC, MEAG Power, Dalton, FP&L, and JEA. Georgia Power has been contracted to operate and maintain the plants as agent for the co-owners and is jointly and severally liable for third party claims related to these plants. (d)Unit 4 remains under construction. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. (e)Jointly owned with OPC, which is the operator of the plant. (f)Jointly owned by FP&L and Mississippi Power. In accordance with the operating agreement, Mississippi Power acts as FP&L's agent with respect to the operation and maintenance of these units. See Note 3 under "Other Matters – Mississippi Power – Plant Daniel" for additional information. (g)Jointly owned with The Williams Companies, Inc., the Dalton Pipeline is a 115-mile natural gas pipeline that serves as an extension of the Transcontinental Gas Pipe Line Company, LLC pipeline system into northwest Georgia. Southern Company Gas leases its 50% undivided ownership for approximately $26 million annually through 2042. The lessee is responsible for maintaining the pipeline during the lease term and for providing service to transportation customers under its FERC-regulated tariff. The Registrants' proportionate share of their jointly-owned facility operating expenses is included in the corresponding operating expenses in the statements of income and each Registrant is responsible for providing its own financing. Assets Subject to Lien Mississippi Power provides retail service to its largest retail customer, Chevron Products Company (Chevron), at its refinery in Pascagoula, Mississippi through at least 2038 in accordance with agreements approved by the Mississippi PSC. The agreements grant Chevron a security interest in the co-generation assets located at the refinery and owned by Mississippi Power, with a lease receivable balance of $147 million at December 31, 2023, that is exercisable upon the occurrence of (i) certain bankruptcy events or (ii) other events of default coupled with specific reductions in steam output at the facility and a downgrade of Mississippi Power's credit rating to below investment grade by two of the three rating agencies. See Note 9 under "Lessor" for additional information. See Note 8 under "Long-term Debt" for information regarding debt secured by certain assets of Georgia Power and Southern Company Gas. 6. ASSET RETIREMENT OBLIGATIONS AROs are computed as the present value of the estimated costs for an asset's future retirement and are recorded in the period in which the liability is incurred. The estimated costs are capitalized as part of the related long-lived asset and depreciated over the asset's useful life. In the absence of quoted market prices, AROs are estimated using present value techniques in which estimates of future cash outlays associated with the asset retirements are discounted using a credit-adjusted risk-free rate. Estimates of the timing and amounts of future cash outlays are based on projections of when and how the assets will be retired and the cost of future removal activities. Each traditional electric operating company and natural gas distribution utility has received accounting guidance from its state PSC or applicable state regulatory agency allowing the continued accrual or recovery of other retirement costs for long-lived assets that it does not have a legal obligation to retire. Accordingly, the accumulated removal costs for these obligations are reflected in the balance sheets as regulatory liabilities and amounts to be recovered are reflected in the balance sheets as regulatory assets. The ARO liabilities for the traditional electric operating companies primarily relate to facilities that are subject to the CCR Rule and the related state rules, principally ash ponds. In addition, Alabama Power and Georgia Power have retirement obligations related to the decommissioning of nuclear facilities (Alabama Power's Plant Farley and Georgia Power's ownership interests in Plant Hatch and Plant Vogtle Units 1 through 3). See "Nuclear Decommissioning" herein for additional information. Other significant AROs include various landfill sites and asbestos removal for Alabama Power, Georgia Power, and Mississippi Power and gypsum cells and mine reclamation for Mississippi Power. The ARO liability for Southern Power primarily relates to its solar and wind facilities, which are located on long-term land leases requiring the restoration of land at the end of the lease. The traditional electric operating companies and Southern Company Gas also have identified other retirement obligations, such as obligations related to certain electric transmission and distribution facilities, certain asbestos-containing material within long-term assets not subject to ongoing repair and maintenance activities, certain wireless communication towers, the disposal of polychlorinated biphenyls in certain transformers, leasehold improvements, equipment on customer property, and property associated with the Southern Company system's rail lines and natural gas pipelines. However, liabilities for the removal of these assets have not been recorded because the settlement timing for certain retirement obligations related to these assets is indeterminable and, therefore, the fair value of the retirement obligations cannot be reasonably estimated. A liability for these retirement obligations will be recognized when sufficient information becomes available to support a reasonable estimation of the ARO. Southern Company and the traditional electric operating companies will continue to recognize in their respective statements of income allowed removal costs in accordance with regulatory treatment. Any differences between costs recognized in accordance with accounting standards related to asset retirement and environmental obligations and those reflected in rates are recognized as either a regulatory asset or liability in the balance sheets as ordered by the various state PSCs. Details of the AROs included in the balance sheets are as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power(*)
| (in millions)
Balance at December 31, 2021 | $ 11,687 | $ 4,334 | $ 6,824 | $ 190 | $ 131
Liabilities incurred | 36 | — | 35 | — | —
Liabilities settled | (455) | (205) | (212) | (20) | —
Accretion expense | 406 | 158 | 231 | 6 | 6
Cash flow revisions | (834) | — | (844) | 3 | 7
Balance at December 31, 2022 | $ 10,840 | $ 4,287 | $ 6,034 | $ 179 | $ 144
Liabilities incurred | 90 | — | 90 | — | —
Liabilities settled | (617) | (270) | (304) | (18) | —
Accretion expense | 403 | 156 | 230 | 5 | 6
Cash flow revisions | (399) | (15) | (385) | 2 | —
Balance at December 31, 2023 | $ 10,317 | $ 4,158 | $ 5,665 | $ 168 | $ 150
*Included in other deferred credits and liabilities on Southern Power's consolidated balance sheets. In December 2022, Georgia Power recorded a net decrease of approximately $780 million to its AROs related to the CCR Rule and the related state rule resulting from changes in estimates, including lower future inflation rates, higher discount rates, and timing of closure activities, as well as a change in closure methodology for one ash pond as approved in Georgia Power's 2022 IRP. Following initial criticality for Plant Vogtle Unit 3 on March 6, 2023, Georgia Power recorded AROs of approximately $90 million. Subsequent to December 31, 2023, Plant Vogtle Unit 4 achieved initial criticality, which will result in Georgia Power recording AROs of approximately $118 million during the first quarter 2024. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. In September 2023 and November 2023, Georgia Power recorded net decreases of approximately $175 million and $210 million, respectively, to its AROs related to the CCR Rule and the related state rule resulting from changes in estimates, including lower future inflation rates and the timing of closure activities. In June 2023, Alabama Power completed an updated decommissioning cost site study for Plant Farley. The estimated cost of decommissioning based on the study resulted in a decrease in Alabama Power's ARO liability of approximately $15 million. See "Nuclear Decommissioning" herein for additional information. The cost estimates for AROs related to the disposal of CCR are based on information at December 31, 2023 using various assumptions related to closure and post-closure costs, timing of future cash outlays, inflation and discount rates, and the potential methods for complying with the CCR Rule and the related state rules. The traditional electric operating companies have periodically updated, and expect to continue periodically updating, their related cost estimates and ARO liabilities for each CCR unit as additional information related to these assumptions becomes available. Some of these updates have been, and future updates may be, material. The cost estimates for Alabama Power are based on closure-in-place for all ash ponds. The cost estimates for Georgia Power and Mississippi Power are based on a combination of closure-in-place for some ash ponds and closure by removal for others. Additionally, the closure designs and plans in the States of Alabama and Georgia are subject to approval by environmental regulatory agencies. Absent continued recovery of ARO costs through regulated rates, results of operations, cash flows, and financial condition for Southern Company and the traditional electric operating companies could be materially impacted. The ultimate outcome of these matters cannot be determined at this time. See Note 3 under "General Litigation Matters – Alabama Power" for additional information. Nuclear Decommissioning The NRC requires licensees of commercial nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. Alabama Power and Georgia Power have external trust funds (Funds) to comply with the NRC's regulations. Use of the Funds is restricted to nuclear decommissioning activities. The Funds are managed and invested in accordance with applicable requirements of various regulatory bodies, including the NRC, the FERC, and state PSCs, as well as the IRS. While Alabama Power and Georgia Power are allowed to prescribe an overall investment policy to the Funds' managers, neither Southern Company nor its subsidiaries or affiliates are allowed to engage in the day-to-day management of the Funds or to mandate individual investment decisions. Day-to-day management of the investments in the Funds is delegated to unrelated third-party managers with oversight by the management of Alabama Power and Georgia Power. The Funds' managers are authorized, within certain investment guidelines, to actively buy and sell securities at their own discretion in order to maximize the return on the Funds' investments. The Funds are invested in a tax-efficient manner in a diversified mix of equity and fixed income securities and are reported as trading securities. Alabama Power and Georgia Power record the investment securities held in the Funds at fair value, as disclosed in Note 13, as management believes that fair value best represents the nature of the Funds. Gains and losses, whether realized or unrealized, are recorded in the regulatory liability for AROs in the balance sheets and are not included in net income or OCI. Fair value adjustments and realized gains and losses are determined on a specific identification basis. Investment securities in the Funds for December 31, 2023 and 2022 were as follows:
| Southern Company | Alabama Power | Georgia Power
| (in millions)
At December 31, 2023: |  |  |
Equity securities | $ 1,288 | $ 796 | $ 492
Debt securities | 895 | 277 | 618
Other securities | 239 | 186 | 53
Total investment securities in the Funds | $ 2,422 | $ 1,259 | $ 1,163
At December 31, 2022: |  |  |
Equity securities | $ 1,095 | $ 690 | $ 405
Debt securities | 838 | 267 | 571
Other securities | 210 | 168 | 42
Total investment securities in the Funds(*) | $ 2,143 | $ 1,125 | $ 1,018
*For Southern Company and Georgia Power, these amounts include investment securities pledged to creditors and collateral received and excludes payables related to a securities lending program Georgia Power's Funds previously participated in through the managers of the Funds. Under this program, Georgia Power's Funds' investment securities were loaned to institutional investors for a fee. Securities loaned were fully collateralized by cash, letters of credit, and/or securities issued or guaranteed by the U.S. government or its agencies or instrumentalities. At December 31, 2022, approximately $35 million of the fair market value of Georgia Power's Funds' securities were on loan and pledged to creditors under the Funds' managers' securities lending program. At December 31, 2022, the fair value of the collateral received was approximately $36 million and could only be sold by the borrower upon the return of the loaned securities. The collateral received was treated as a non-cash item in the statements of cash flows. These amounts exclude receivables related to investment income and pending investment sales and payables related to pending investment purchases. The fair value increases (decreases) of the Funds, including unrealized gains (losses) and reinvested interest and dividends and excluding the Funds' expenses, for 2023, 2022, and 2021 are shown in the table below.
| Southern Company | Alabama Power | Georgia Power
| (in millions)
Fair value increases (decreases) |  |  |
2023 | $ 281 | $ 157 | $ 124
2022 | (360) | (171) | (189)
2021 | 274 | 200 | 74
Unrealized gains (losses) |  |  |
At December 31, 2023 | $ 241 | $ 119 | $ 122
At December 31, 2022 | (391) | (204) | (187)
At December 31, 2021 | (27) | (30) | 3
The investment securities held in the Funds continue to be managed with a long-term focus. Accordingly, all purchases and sales within the Funds are presented separately in the statements of cash flows as investing cash flows, consistent with the nature of the securities and purpose for which the securities were acquired. For Alabama Power, approximately $13 million and $14 million at December 31, 2023 and 2022, respectively, previously recorded in internal reserves is being transferred into the Funds through 2040 as approved by the Alabama PSC. The NRC's minimum external funding requirements are based on a generic estimate of the cost to decommission only the radioactive portions of a nuclear unit based on the size and type of reactor. Alabama Power and Georgia Power have filed plans with the NRC designed to ensure that, over time, the deposits and earnings of the Funds will provide the minimum funding amounts prescribed by the NRC. At December 31, 2023 and 2022, the accumulated provisions for the external decommissioning trust funds were as follows:
| 2023 |  | 2022
| (in millions)
Alabama Power |  |  |
Plant Farley | $ 1,259 |  | $ 1,125
Georgia Power |  |  |
Plant Hatch | $ 705 |  | $ 628
Plant Vogtle Units 1 and 2 | 434 |  | 382
Plant Vogtle Units 3 and 4 | 24 |  | 8
Total | $ 1,163 |  | $ 1,018
Site study cost is the estimate to decommission a specific facility as of the site study year. The decommissioning cost estimates are based on removal of the plant from service and prompt dismantlement. The actual decommissioning costs may vary from these estimates because of changes in the assumed date of decommissioning, changes in NRC requirements, or changes in the assumptions used in making these estimates. The estimated costs of decommissioning at December 31, 2023 based on the most current studies were as follows:
| Alabama Power |  | Georgia Power
| Plant Farley |  | Plant Hatch(*) |  | Plant Vogtle Units 1 and 2(*) |  | Plant Vogtle Unit 3(*)
Most current study year | 2023 |  | 2021 |  | 2021 |  | 2020
Decommissioning periods: |  |  |  |  |  |  |
Beginning year | 2037 |  | 2034 |  | 2047 |  | 2063
Completion year | 2087 |  | 2075 |  | 2079 |  | 2074
| (in millions)
Site study costs: |  |  |  |  |  |  |
Radiated structures | $ 1,402 |  | $ 771 |  | $ 628 |  | $ 284
Spent fuel management | 513 |  | 186 |  | 170 |  | 30
Non-radiated structures | 133 |  | 61 |  | 85 |  | 33
Total site study costs | $ 2,048 |  | $ 1,018 |  | $ 883 |  | $ 347
*Based on Georgia Power's ownership interests. For ratemaking purposes, Alabama Power's decommissioning costs are based on the site study and Georgia Power's decommissioning costs are based on the NRC generic estimate to decommission the radioactive portion of the facilities and the site study estimate for spent fuel management. Significant assumptions used to determine these costs for ratemaking were an estimated inflation rate of 4.5% for Plant Farley, 2.5% for Plants Hatch and Vogtle Units 1 and 2, and 2.4% for Plant Vogtle Unit 3 and an estimated trust earnings rate of 7.0% for Plant Farley, 4.5% for Plants Hatch and Vogtle Units 1 and 2, and 4.4% for Plant Vogtle Unit 3. Amounts previously contributed to the Funds for Plant Farley are currently projected to be adequate to meet the decommissioning obligations. Alabama Power's site-specific estimates of decommissioning costs for Plant Farley are updated every five years. The next site study for Alabama Power is expected to be completed in 2028. Projections of funds are reviewed with the Alabama PSC to ensure that, over time, the deposits and earnings of the Funds will provide adequate funding to cover the site-specific costs. If necessary, Alabama Power would seek the Alabama PSC's approval to address any changes in a manner consistent with NRC and other applicable requirements. Under the 2019 ARP, Georgia Power's annual decommissioning cost for ratemaking in 2021 and 2022 was a total of $4 million for Plant Hatch and Plant Vogtle Units 1 and 2. Effective January 1, 2023, as approved in the 2022 ARP, there is no annual decommissioning cost for ratemaking for Plant Hatch and Plant Vogtle Units 1 and 2. Any funding amount required by the NRC during the period covered by the 2022 ARP will be deferred to a regulatory asset and recovery is expected to be determined in Georgia Power's next base rate case. See Note 2 under "Georgia Power – Rate Plans – 2022 ARP" for additional information. Effective August 1, 2023, as approved under the Plant Vogtle Unit 3 and Common Facilities rate proceeding, Georgia Power's annual decommissioning cost for ratemaking is $8 million for Plant Vogtle Unit 3. See Note 2 under "Georgia Power – Nuclear Construction – Regulatory Matters" for additional information. 7. CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS The Registrants may hold ownership interests in a number of business ventures with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE. If a venture is a VIE for which a Registrant is the primary beneficiary, the assets, liabilities, and results of operations of the entity are consolidated. The Registrants reassess the conclusion as to whether an entity is a VIE upon certain occurrences, which are deemed reconsideration events. For entities that are not determined to be VIEs, the Registrants evaluate whether they have control or significant influence over the investee to determine the appropriate consolidation and presentation. Generally, entities under the control of a Registrant are consolidated, and entities over which a Registrant can exert significant influence, but which a Registrant does not control, are accounted for under the equity method of accounting. Investments accounted for under the equity method are recorded within equity investments in unconsolidated subsidiaries in the balance sheets and, for Southern Company and Southern Company Gas, the equity income is recorded within earnings from equity method investments in the statements of income. See "SEGCO" and "Southern Company Gas" herein for additional information. Southern Company At December 31, 2023 and 2022, Southern Holdings had equity method investments totaling $126 million and $112 million, respectively, primarily related to investments in venture capital funds focused on energy and utility investments. Earnings from these investments were immaterial for all periods presented. SEGCO Alabama Power and Georgia Power own equally all of the outstanding capital stock of SEGCO, which owns electric generating units at Plant Gaston with a total rated capacity of 1,020 MWs, as well as associated transmission facilities. Retirement of SEGCO's generating units is currently expected to occur by December 31, 2028. However, Alabama Power, in conjunction with Georgia Power, is evaluating extending the operation of Plant Gaston Units 1 through 4 beyond the indicated retirement date. See Note 2 under "Georgia Power – Integrated Resource Plans" for additional information. Alabama Power and Georgia Power account for SEGCO using the equity method; Southern Company consolidates SEGCO. The capacity of these units is sold equally to Alabama Power and Georgia Power. Alabama Power and Georgia Power make payments sufficient to provide for the operating expenses, taxes, interest expense, and a ROE. The share of purchased power included in purchased power, affiliates in the statements of income totaled $112 million in 2023, $124 million in 2022, and $75 million in 2021 for Alabama Power and $115 million in 2023, $127 million in 2022, and $77 million in 2021 for Georgia Power. SEGCO paid dividends of $25 million in 2023, $14 million in 2022, and $14 million in 2021, one half of which were paid to each of Alabama Power and Georgia Power. In addition, Alabama Power and Georgia Power each recognize 50% of SEGCO's net income. Alabama Power, which owns and operates a generating unit adjacent to the SEGCO generating units, has a joint ownership agreement with SEGCO for the ownership of an associated gas pipeline. Alabama Power owns 14% of the pipeline with the remaining 86% owned by SEGCO. See Note 3 under "Guarantees" for additional information regarding guarantees of Alabama Power and Georgia Power related to SEGCO. Southern Power Variable Interest Entities Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the obligation to absorb expected losses of these VIEs to the extent of its equity interests. SP Solar and SP Wind SP Solar is owned by Southern Power and a limited partner. A wholly-owned subsidiary of Southern Power is the general partner and holds a 1% ownership interest, and another wholly-owned subsidiary of Southern Power owns a 66% ownership interest. The limited partner holds the remaining 33% noncontrolling interest. SP Solar qualifies as a VIE since the arrangement is structured as a limited partnership and the 33% limited partner does not have substantive kick-out rights against the general partner. At December 31, 2023 and 2022, SP Solar had total assets of $5.6 billion and $5.9 billion, respectively, total liabilities of $0.4 billion, and noncontrolling interests of $1.0 billion and $1.1 billion, respectively. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to the limited partner in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. SP Wind is owned by Southern Power and three financial investors. A wholly-owned subsidiary of Southern Power owns 100% of the Class B membership interests and the three financial investors own 100% of the Class A membership interests. SP Wind qualifies as a VIE since the structure of the arrangement is similar to a limited partnership and the Class A members do not have substantive kick-out rights against Southern Power. At December 31, 2023 and 2022, SP Wind had total assets of $2.1 billion and $2.2 billion, respectively, total liabilities of $187 million and $169 million, respectively, and noncontrolling interests of $38 million and $39 million, respectively. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three financial investors in accordance with the limited liability agreement. Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt. Other Variable Interest Entities Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights. At December 31, 2023 and 2022, the other VIEs had total assets of $1.7 billion and $1.8 billion, respectively, total liabilities of $0.2 billion, and noncontrolling interests of $0.8 billion. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent. Equity Method Investments During 2023 and 2022, Southern Power sold its remaining equity method investments in wind projects and received proceeds totaling $50 million and $38 million, respectively. Earnings (loss) from these investments, including the gains associated with the sales, were immaterial for all periods presented. Southern Company Gas Equity Method Investments The carrying amounts of Southern Company Gas' equity method investments at December 31, 2023 and 2022 and related earnings (loss) from those investments for the years ended December 31, 2023, 2022, and 2021 were as follows:
Investment Balance | December 31, 2023 |  | December 31, 2022
| (in millions)
SNG | $ 1,202 |  | $ 1,243
Other | 33 |  | 33
Total | $ 1,235 |  | $ 1,276
Earnings (Loss) from Equity Method Investments | 2023 |  | 2022 |  | 2021
| (in millions)
SNG | $ 139 |  | $ 146 |  | $ 127
PennEast Pipeline(*) | — |  | — |  | (81)
Other | 1 |  | 2 |  | 4
Total | $ 140 |  | $ 148 |  | $ 50
*For 2021, includes pre-tax impairment charges totaling $84 million. See "PennEast Pipeline Project" herein for additional information, including the September 2021 cancellation of the project. PennEast Pipeline Project In 2014, Southern Company Gas entered into a partnership in which it holds a 20% ownership interest in the PennEast Pipeline, an interstate pipeline company formed to develop and operate an approximate 118-mile natural gas pipeline between New Jersey and Pennsylvania. In 2019, an appellate court ruled that the PennEast Pipeline does not have federal eminent domain authority over lands in which a state has property rights interests. In June 2021, the U.S. Supreme Court ruled in favor of PennEast Pipeline following a review of the appellate court decision. Southern Company Gas assesses its equity method investments for impairment whenever events or changes in circumstances indicate that the investment may be impaired. Following the U.S. Supreme Court ruling, during the second quarter 2021, Southern Company Gas management reassessed the project construction timing, including the anticipated timing for receipt of a FERC certificate and all remaining state and local permits, as well as potential challenges thereto, and performed an impairment analysis. The outcome of the analysis resulted in a pre-tax impairment charge of $82 million ($58 million after tax). In September 2021, PennEast Pipeline announced that further development of the project was no longer supported, and, as a result, all further development of the project ceased. During the third quarter 2021, Southern Company Gas recorded an additional pre-tax charge of $2 million ($2 million after tax) related to its share of the project level impairment, as well as $7 million of additional tax expense, resulting in total pre-tax charges of $84 million ($67 million after tax) during 2021 related to the project. 8. FINANCING Long-term Debt Details of long-term debt at December 31, 2023 and 2022 are provided in the following table:
| At December 31, 2023 |  | Balance Outstanding at December 31,
| Maturity |  | Weighted Average Interest Rate |  | 2023 |  | 2022
|  |  |  |  | (in millions)
Southern Company |  |  |  |  |  |  |
Senior notes(a) | 2024-2073 |  | 4.16% |  | $ 40,235 |  | $ 35,683
Junior subordinated notes | 2024-2081 |  | 4.33% |  | 8,333 |  | 8,836
FFB loans(b) | 2024-2044 |  | 2.88% |  | 4,788 |  | 4,874
Revenue bonds(c) | 2024-2063 |  | 3.77% |  | 3,400 |  | 2,844
First mortgage bonds(d) | 2025-2063 |  | 3.64% |  | 2,500 |  | 2,275
Medium-term notes | 2026-2027 |  | 7.03% |  | 84 |  | 84
Other long-term debt | 2024-2045 |  | 5.44% |  | 234 |  | 167
Finance lease obligations(e) |  |  |  |  | 298 |  | 314
Unamortized fair value adjustment |  |  |  |  | 302 |  | 330
Unamortized debt premium (discount), net |  |  |  |  | (198) |  | (193)
Unamortized debt issuance expenses |  |  |  |  | (290) |  | (273)
Total long-term debt |  |  |  |  | 59,686 |  | 54,941
Less: Amount due within one year |  |  |  |  | 2,476 |  | 4,285
Total long-term debt excluding amount due within one year |  |  |  |  | $ 57,210 |  | $ 50,656
Alabama Power |  |  |  |  |  |  |
Senior notes | 2025-2073 |  | 3.95% |  | $ 9,875 |  | $ 9,675
Revenue bonds(c) | 2024-2063 |  | 3.94% |  | 1,321 |  | 995
Other long-term debt | 2026-2030 |  | 7.04% |  | 75 |  | 45
Finance lease obligations(e) |  |  |  |  | 5 |  | 5
Unamortized debt premium (discount), net |  |  |  |  | (20) |  | (18)
Unamortized debt issuance expenses |  |  |  |  | (73) |  | (72)
Total long-term debt |  |  |  |  | 11,183 |  | 10,630
Less: Amount due within one year |  |  |  |  | 223 |  | 301
Total long-term debt excluding amount due within one year |  |  |  |  | $ 10,960 |  | $ 10,329
Georgia Power |  |  |  |  |  |  |
Senior notes | 2024-2052 |  | 4.34% |  | $ 9,575 |  | $ 7,925
Junior subordinated notes | 2077 |  | 5.00% |  | 270 |  | 270
FFB loans(b) | 2024-2044 |  | 2.88% |  | 4,788 |  | 4,874
Revenue bonds(c) | 2025-2062 |  | 3.64% |  | 1,968 |  | 1,738
Finance lease obligations(e) |  |  |  |  | 240 |  | 238
Unamortized debt premium (discount), net |  |  |  |  | (19) |  | (18)
Unamortized debt issuance expenses |  |  |  |  | (122) |  | (117)
Total long-term debt |  |  |  |  | 16,700 |  | 14,910
Less: Amount due within one year |  |  |  |  | 502 |  | 901
Total long-term debt excluding amount due within one year |  |  |  |  | $ 16,198 |  | $ 14,009
Mississippi Power |  |  |  |  |  |  |
Senior notes | 2024-2051 |  | 4.27% |  | $ 1,525 |  | $ 1,425
Revenue bonds(c) | 2025-2052 |  | 4.08% |  | 111 |  | 111
Finance lease obligations(e) |  |  |  |  | 16 |  | 17
Unamortized debt premium (discount), net |  |  |  |  | 1 |  | 2
Unamortized debt issuance expenses |  |  |  |  | (9) |  | (10)
Total long-term debt |  |  |  |  | 1,644 |  | 1,545
Less: Amount due within one year |  |  |  |  | 201 |  | 1
Total long-term debt excluding amount due within one year |  |  |  |  | $ 1,443 |  | $ 1,544
Southern Power |  |  |  |  |  |  |
Senior notes(a) | 2025-2046 |  | 4.05% |  | $ 2,728 |  | $ 2,998
Unamortized debt premium (discount), net |  |  |  |  | (4) |  | (5)
Unamortized debt issuance expenses |  |  |  |  | (13) |  | (14)
Total long-term debt |  |  |  |  | 2,711 |  | 2,979
Less: Amount due within one year |  |  |  |  | — |  | 290
Total long-term debt excluding amount due within one year |  |  |  |  | $ 2,711 |  | $ 2,689
Southern Company Gas |  |  |  |  |  |  |
Senior notes | 2025-2051 |  | 4.36% |  | $ 4,930 |  | $ 4,769
First mortgage bonds(d) | 2025-2063 |  | 3.64% |  | 2,500 |  | 2,275
Medium-term notes | 2026-2027 |  | 7.03% |  | 84 |  | 84
Other long-term debt | 2024-2045 |  | 3.81% |  | 59 |  | 22
Unamortized fair value adjustment |  |  |  |  | 302 |  | 330
Unamortized debt premium (discount), net |  |  |  |  | (8) |  | (8)
Unamortized debt issuance expenses |  |  |  |  | (34) |  | (30)
Total long-term debt |  |  |  |  | 7,833 |  | 7,442
Less: Amount due within one year |  |  |  |  | — |  | 400
Total long-term debt excluding amount due within one year |  |  |  |  | $ 7,833 |  | $ 7,042
(a)Includes a fair value gain (loss) of $(12) million and $(31) million at December 31, 2023 and 2022, respectively, related to Southern Power's foreign currency hedge on its euro-denominated senior notes. (b)Secured by a first priority lien on (i) Georgia Power's undivided ownership interest in Plant Vogtle Units 3 and 4 (primarily the units, the related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power's rights and obligations under the principal contracts relating to Plant Vogtle Units 3 and 4. See "DOE Loan Guarantee Borrowings" herein for additional information. (c)Revenue bond obligations represent loans to the traditional electric operating companies from public authorities of funds derived from sales by such authorities of revenue bonds issued to finance pollution control and solid waste disposal and wastewater facilities. In some cases, the revenue bond obligations represent obligations under installment sales agreements with respect to facilities constructed with the proceeds of revenue bonds issued by public authorities. The traditional electric operating companies are required to make payments sufficient for the authorities to meet principal and interest requirements of such bonds. Proceeds from certain issuances are restricted until qualifying expenditures are incurred. (d)Secured by substantially all of Nicor Gas' properties. (e)Secured by the underlying lease ROU asset. See Note 9 for additional information. Maturities of long-term debt for the next five years are as follows:
| Southern Company(a) | Alabama Power(b) | Georgia Power(c) | Mississippi Power | Southern Power(d) | Southern Company Gas
| (in millions)
2024 | $ 2,480 | $ 223 | $ 503 | $ 201 | $ — | $ —
2025 | 4,124 | 251 | 849 | 12 | 500 | 300
2026 | 3,791 | 46 | 448 | 66 | 964 | 530
2027 | 2,075 | 551 | 512 | 10 | — | 154
2028 | 2,612 | 107 | 864 | 357 | — | 150
(a)See notes (b) and (c) below. (b)Alabama Power's 2024 maturities include $200 million aggregate principal amount of Series 2023A Floating Rate Senior Notes due May 15, 2073 that are repayable at the option of the holders at certain dates beginning in 2024. As a result, the senior notes are classified as securities due within one year on the balance sheets of Southern Company and Alabama Power at December 31, 2023. (c)Amounts include principal amortization related to the FFB borrowings; however, the final maturity date is February 20, 2044. See "DOE Loan Guarantee Borrowings" herein for additional information. (d)Southern Power's 2026 maturities include $564 million of euro-denominated debt at the U.S. dollar denominated hedge settlement amount. DOE Loan Guarantee Borrowings Pursuant to the loan guarantee program established under Title XVII of the Energy Policy Act of 2005 (Title XVII Loan Guarantee Program), Georgia Power and the DOE entered into a loan guarantee agreement in 2014 and the Amended and Restated Loan Guarantee Agreement in 2019. Under the Amended and Restated Loan Guarantee Agreement, the DOE agreed to guarantee the obligations of Georgia Power under the FFB Credit Facilities. Under the FFB Credit Facilities, Georgia Power was authorized to make term loan borrowings through the FFB in an amount up to approximately $5.130 billion, provided that total aggregate borrowings under the FFB Credit Facilities could not exceed 70% of (i) Eligible Project Costs minus (ii) approximately $1.492 billion (reflecting the amounts received by Georgia Power under the Guarantee Settlement Agreement less the related customer refunds). In 2021, Georgia Power made the final borrowings under the FFB Credit Facilities and no further borrowings are permitted. During 2023, Georgia Power made principal amortization payments of $86 million under the FFB Credit Facilities. At December 31, 2023 and 2022, Georgia Power had $4.8 billion and $4.9 billion of borrowings outstanding under the FFB Credit Facilities, respectively. All borrowings under the FFB Credit Facilities are full recourse to Georgia Power, and Georgia Power is obligated to reimburse the DOE for any payments the DOE is required to make to the FFB under its guarantee. Georgia Power's reimbursement obligations to the DOE are full recourse and secured by a first priority lien on (i) Georgia Power's undivided ownership interest in Plant Vogtle Units 3 and 4 (primarily the units, the related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power's rights and obligations under the principal contracts relating to Plant Vogtle Units 3 and 4. There are no restrictions on Georgia Power's ability to grant liens on other property. The final maturity date for each advance under the FFB Credit Facilities is February 20, 2044. Interest is payable quarterly and principal payments began in 2020. Each borrowing under the FFB Credit Facilities bears interest at a fixed rate equal to the applicable U.S. Treasury rate at the time of the borrowing plus a spread equal to 0.375%. Under the Amended and Restated Loan Guarantee Agreement, Georgia Power is subject to customary borrower affirmative and negative covenants and events of default. In addition, Georgia Power is subject to project-related reporting requirements and other project-specific covenants and events of default. In the event certain mandatory prepayment events occur, Georgia Power will be required to prepay the outstanding principal amount of all borrowings under the FFB Credit Facilities over a period of five years (with level principal amortization). Among other things, these mandatory prepayment events include (i) the termination of the Vogtle Services Agreement or rejection of the Vogtle Services Agreement in any Westinghouse bankruptcy if Georgia Power does not maintain access to intellectual property rights under the related intellectual property licenses; (ii) termination of the Bechtel Agreement by Bechtel or in connection with a cancellation of Plant Vogtle Units 3 and 4, unless the Vogtle Owners enter into a replacement agreement; (iii) cancellation of Plant Vogtle Unit 4 by the Georgia PSC or by Georgia Power; (iv) failure of the holders of 90% of the ownership interests in Plant Vogtle Units 3 and 4 to vote to continue construction following certain schedule extensions; (v) cost disallowances by the Georgia PSC that could have a material adverse effect on completion of Plant Vogtle Unit 4 or Georgia Power's ability to repay the outstanding borrowings under the FFB Credit Facilities; or (vi) loss of or failure to receive necessary regulatory approvals. Under certain circumstances, insurance proceeds and any proceeds from an event of taking must be applied to immediately prepay outstanding borrowings under the FFB Credit Facilities. Georgia Power also may voluntarily prepay outstanding borrowings under the FFB Credit Facilities. Under the FFB Credit Facilities, any prepayment (whether mandatory or optional) will be made with a make-whole premium or discount, as applicable. In connection with any cancellation of Plant Vogtle Unit 4, the DOE may elect to continue construction of Plant Vogtle Unit 4. In such an event, the DOE will have the right to assume Georgia Power's rights and obligations under the principal agreements relating to Plant Vogtle Units 3 and 4 and to acquire all or a portion of Georgia Power's ownership interest in Plant Vogtle Units 3 and 4. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. Secured Debt Each of Southern Company's subsidiaries is organized as a legal entity, separate and apart from Southern Company and its other subsidiaries. There are no agreements or other arrangements among the Southern Company system companies under which the assets of one company have been pledged or otherwise made available to satisfy obligations of Southern Company or any of its other subsidiaries. As discussed under "Long-term Debt" herein, the Registrants had secured debt outstanding at December 31, 2023 and 2022. Each Registrant's senior notes, junior subordinated notes, revenue bond obligations, bank term loans, credit facility borrowings, and notes payable are effectively subordinated to all secured debt of each respective Registrant. Equity Units In May 2022, Southern Company remarketed $862.5 million aggregate principal amount of its Series 2019A Remarketable Junior Subordinated Notes due August 1, 2024 (2019A RSNs) and $862.5 million aggregate principal amount of its Series 2019B Remarketable Junior Subordinated Notes due August 1, 2027 (2019B RSNs), pursuant to the terms of its 2019 Series A Equity Units (Equity Units). In connection with the remarketing, the interest rates on the 2019A RSNs and the 2019B RSNs were reset to 4.475% and 5.113%, respectively, payable on a semi-annual basis. In August 2022, the proceeds were ultimately used to settle the purchase contracts entered into as part of the Equity Units and Southern Company issued approximately 25.2 million shares of common stock and received proceeds of $1.725 billion. At December 31, 2023 and 2022, the 2019A RSNs and the 2019B RSNs are included on Southern Company's consolidated balance sheets in long-term debt or, as applicable, securities due within one year. Convertible Senior Notes In February 2023, Southern Company issued $1.5 billion aggregate principal amount of Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 (Series 2023A Convertible Senior Notes). In March 2023, Southern Company issued an additional $225 million aggregate principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers of their over-allotment option. Interest on the Series 2023A Convertible Senior Notes is payable semiannually, which began on June 15, 2023. The Series 2023A Convertible Senior Notes will mature on December 15, 2025, unless earlier converted or repurchased, but are not redeemable at the option of Southern Company. The Series 2023A Convertible Senior Notes are direct, unsecured, and unsubordinated obligations of Southern Company, ranking equally with all of Southern Company's other unsecured and unsubordinated indebtedness from time to time outstanding, and are effectively subordinated to all secured indebtedness of Southern Company. Holders may convert their Series 2023A Convertible Senior Notes at their option prior to the close of business on the business day preceding September 15, 2025, but only under the following circumstances: *during any calendar quarter (and only during such calendar quarter), if the last reported sale price of Southern Company's common stock for at least 20 trading days (whether or not consecutive) during the period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day as determined by Southern Company; *during the five business day period after any 10 consecutive trading day period (Measurement Period) in which the trading price per $1,000 principal amount of Series 2023A Convertible Senior Notes for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price of the common stock and the conversion rate on each such trading day; or *upon the occurrence of certain corporate events specified in the indenture governing the Series 2023A Convertible Senior Notes. On or after September 15, 2025, a holder may convert all or any portion of its Series 2023A Convertible Senior Notes at any time prior to the close of business on the second scheduled trading day immediately preceding the maturity date regardless of the foregoing conditions. Southern Company will settle conversions of the Series 2023A Convertible Senior Notes by paying cash up to the aggregate principal amount of the Series 2023A Convertible Senior Notes to be converted and paying or delivering, as the case may be, cash, shares of common stock or a combination of cash and shares of common stock, at Southern Company's election, in respect of the remainder, if any, of Southern Company's conversion obligation in excess of the aggregate principal amount of the Series 2023A Convertible Senior Notes being converted. The Series 2023A Convertible Senior Notes are initially convertible at a rate of 11.8818 shares of common stock per $1,000 principal amount converted, which is approximately equal to $84.16 per share of common stock. The conversion rate will be subject to adjustment upon the occurrence of certain specified events but will not be adjusted for accrued and unpaid interest. In addition, upon the occurrence of a make-whole fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), Southern Company will, in certain circumstances, increase the conversion rate by a number of additional shares of common stock for conversions in connection with the make-whole fundamental change. Upon the occurrence of a fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), holders of the Series 2023A Convertible Senior Notes may require Southern Company to purchase all or a portion of their Series 2023A Convertible Senior Notes, in principal amounts equal to $1,000 or an integral multiple thereof, for cash at a price equal to 100% of the principal amount of the Series 2023A Convertible Senior Notes to be purchased plus any accrued and unpaid interest. Bank Credit Arrangements At December 31, 2023, committed credit arrangements with banks were as follows:
| Expires |  |  |
Company | 2024 |  | 2025 |  | 2026 |  | 2028 |  | Total |  | Unused |  | Expires within One Year
| (in millions)
Southern Company parent(a) | $ 150 |  | $ — |  | $ — |  | $ 1,850 |  | $ 2,000 |  | $ 1,998 |  | $ 150
Alabama Power | — |  | — |  | 650 |  | 700 |  | 1,350 |  | 1,350 |  | —
Georgia Power | — |  | — |  | — |  | 1,750 |  | 1,750 |  | 1,726 |  | —
Mississippi Power | — |  | 125 |  | 150 |  | — |  | 275 |  | 275 |  | —
Southern Power(a)(b) | — |  | — |  | — |  | 600 |  | 600 |  | 589 |  | —
Southern Company Gas(c) | 100 |  | — |  | — |  | 1,500 |  | 1,600 |  | 1,598 |  | 100
SEGCO | 30 |  | — |  | — |  | — |  | 30 |  | 30 |  | 30
Southern Company | $ 280 |  | $ 125 |  | $ 800 |  | $ 6,400 |  | $ 7,605 |  | $ 7,566 |  | $ 280
(a)Arrangement expiring in 2028 represents a $2.45 billion combined arrangement for Southern Company and Southern Power as borrowers. Pursuant to the combined facility, the allocations between Southern Company and Southern Power may be adjusted. (b)Does not include Southern Power Company's $75 million and $100 million continuing letter of credit facilities for standby letters of credit, expiring in 2025 and 2026, respectively, of which $8 million and $7 million, respectively, was unused at December 31, 2023. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities. (c)Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of the credit arrangement expiring in 2028. Southern Company Gas' committed credit arrangement expiring in 2028 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2028, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower under a $100 million credit arrangement expiring in 2024. See "Structural Considerations" herein for additional information. The bank credit arrangements require payment of commitment fees based on the unused portion of the commitments. Commitment fees average less than 1/4 of 1% for the Registrants and Nicor Gas. Subject to applicable market conditions, Southern Company and its subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern Company and its subsidiaries may extend the maturity dates and/or increase or decrease the lending commitments thereunder. These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness of the individual company. The cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. Southern Company's, certain of Mississippi Power's, Southern Company Gas', and Nicor Gas' credit arrangements contain covenants that limit debt levels to 70% of total capitalization, as defined in the agreements, and the other subsidiaries' bank credit arrangements contain covenants that limit debt levels to 65% of total capitalization, as defined in the agreements. For purposes of these definitions, debt excludes junior subordinated notes and, in certain arrangements, other hybrid securities. Additionally, for Southern Company and Southern Power, for purposes of these definitions, debt excludes any project debt incurred by certain subsidiaries of Southern Power to the extent such debt is non-recourse to Southern Power and capitalization excludes the capital stock or other equity attributable to such subsidiaries. At December 31, 2023, the Registrants, Nicor Gas, and SEGCO were in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings. A portion of the unused credit with banks is allocated to provide liquidity support to certain revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. At December 31, 2023, outstanding variable rate demand revenue bonds of the traditional electric operating companies with allocated liquidity support totaled approximately $1.7 billion (comprised of approximately $818 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi Power). In addition, at December 31, 2023, Georgia Power had approximately $325 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months. The variable rate demand revenue bonds and fixed rate revenue bonds required to be remarketed within the next 12 months are classified as long-term debt on the balance sheets as a result of available long-term committed credit. At both December 31, 2023 and 2022, Southern Power had $106 million of cash collateral posted related to PPA requirements, which is included in other deferred charges and assets on Southern Power's consolidated balance sheets. Notes Payable The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity support of the committed bank credit arrangements described above under "Bank Credit Arrangements." Southern Power's subsidiaries are not parties or obligors to its commercial paper program. Southern Company Gas maintains commercial paper programs at Southern Company Gas Capital and at Nicor Gas. Nicor Gas' commercial paper program supports working capital needs at Nicor Gas as Nicor Gas is not permitted to make money pool loans to affiliates. All of Southern Company Gas' other subsidiaries benefit from Southern Company Gas Capital's commercial paper program. See "Structural Considerations" herein for additional information. In addition, Southern Company and certain of its subsidiaries have entered into various bank term loan agreements. Unless otherwise stated, the proceeds of these loans were used to repay existing indebtedness and for general corporate purposes, including working capital and, for the subsidiaries, their continuous construction programs. Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details of short-term borrowings for the applicable Registrants were as follows:
| Notes Payable at December 31, 2023 |  | Notes Payable at December 31, 2022
| Amount Outstanding |  | Weighted Average Interest Rate |  | Amount Outstanding |  | Weighted Average Interest Rate
| (in millions) |  |  |  | (in millions) |  |
Southern Company |  |  |  |  |  |  |
Commercial paper | $ 1,794 |  | 5.6 % |  | $ 809 |  | 4.7 %
Short-term bank debt | 520 |  | 6.4 % |  | 1,800 |  | 5.0 %
Total | $ 2,314 |  | 5.7 % |  | $ 2,609 |  | 4.9 %
Alabama Power |  |  |  |  |  |  |
Commercial paper | $ 40 |  | 5.5 % |  | $ — |  | — %
Georgia Power |  |  |  |  |  |  |
Commercial paper | $ 809 |  | 5.6 % |  | $ — |  | — %
Short-term bank debt | 520 |  | 6.4 % |  | 1,600 |  | 5.0 %
Total | $ 1,329 |  | 5.9 % |  | $ 1,600 |  | 5.0 %
Southern Power |  |  |  |  |  |  |
Commercial paper | $ 138 |  | 5.5 % |  | $ 225 |  | 4.7 %
Southern Company Gas |  |  |  |  |  |  |
Commercial paper: |  |  |  |  |  |  |
Southern Company Gas Capital | $ 23 |  | 5.5 % |  | $ 285 |  | 4.8 %
Nicor Gas | 392 |  | 5.5 % |  | 283 |  | 4.6 %
Short-term bank debt: |  |  |  |  |  |  |
Nicor Gas | — |  | — % |  | 200 |  | 4.9 %
Total | $ 415 |  | 5.5 % |  | $ 768 |  | 4.7 %
See "Bank Credit Arrangements" herein for information on bank term loan covenants that limit debt levels and cross-acceleration or cross-default provisions. Outstanding Classes of Capital Stock Southern Company Common Stock Stock Issued During 2023, Southern Company issued approximately 2.1 million shares of common stock primarily through equity compensation plans and received proceeds of approximately $36 million. Shares Reserved At December 31, 2023, a total of 131 million shares were reserved for issuance pursuant to the Southern Investment Plan, employee savings plans, the Equity and Incentive Compensation Plan (which includes stock options and performance share units as discussed in Note 12), an at-the-market program, and the Series 2023A Convertible Senior Notes (as discussed under "Convertible Senior Notes" herein). Of the shares reserved, 26.9 million shares are available for awards under the Equity and Incentive Compensation Plan at December 31, 2023. Diluted Earnings Per Share For Southern Company, the only difference in computing basic and diluted earnings per share (EPS) is attributable to awards outstanding under stock-based compensation plans and the Series 2023A Convertible Senior Notes. EPS dilution resulting from stock-based compensation plans is determined using the treasury stock method and EPS dilution resulting from the Series 2023A Convertible Senior Notes is determined using the net share settlement method. See Note 12 and "Convertible Senior Notes" herein for additional information. Shares used to compute diluted EPS were as follows:
| Average Common Stock Shares
| 2023 |  | 2022 |  | 2021
| (in millions)
As reported shares | 1,092 |  | 1,075 |  | 1,061
Effect of stock-based compensation | 6 |  | 6 |  | 7
Diluted shares | 1,098 |  | 1,081 |  | 1,068
For 2023, there were no anti-dilutive shares. For 2022 and 2021, an immaterial number of stock-based compensation awards was excluded from the diluted EPS calculation because the awards were anti-dilutive. For all periods presented, there was no dilution resulting from the Series 2023A Convertible Senior Notes. Preferred Stock of Subsidiaries As discussed further under "Alabama Power" herein, during 2022, Alabama Power redeemed all of its preferred stock and Class A preferred stock. Alabama Power Alabama Power has preferred stock, Class A preferred stock, preference stock, and common stock authorized, but only common stock outstanding at December 31, 2023. During 2022, Alabama Power redeemed all of its preferred stock and Class A preferred stock at the redemption prices per share provided in the table below, plus accrued and unpaid dividends to the redemption date.
Preferred Stock Redeemed During 2022 | Par Value/Stated Capital Per Share |  | Shares |  | Redemption Price Per Share
4.92% Preferred Stock | $100 |  | 80,000 |  | $103.23
4.72% Preferred Stock | $100 |  | 50,000 |  | $102.18
4.64% Preferred Stock | $100 |  | 60,000 |  | $103.14
4.60% Preferred Stock | $100 |  | 100,000 |  | $104.20
4.52% Preferred Stock | $100 |  | 50,000 |  | $102.93
4.20% Preferred Stock | $100 |  | 135,115 |  | $105.00
5.00% Class A Preferred Stock | $25 |  | 10,000,000 |  | $25.00
Georgia Power Georgia Power has preferred stock, Class A preferred stock, preference stock, and common stock authorized, but only common stock outstanding. Mississippi Power Mississippi Power has preferred stock and common stock authorized, but only common stock outstanding. Dividend Restrictions The income of Southern Company is derived primarily from equity in earnings of its subsidiaries. At December 31, 2023, consolidated retained earnings included $5.5 billion of undistributed retained earnings of the subsidiaries. The traditional electric operating companies and Southern Power can only pay dividends to Southern Company out of retained earnings or paid-in-capital. See Note 7 under "Southern Power" for information regarding the distribution requirements for certain Southern Power subsidiaries. By regulation, Nicor Gas is restricted, up to its retained earnings balance, in the amount it can dividend or loan to affiliates and is not permitted to make money pool loans to affiliates. At December 31, 2023, the amount of Southern Company Gas' subsidiary retained earnings available for dividend payment totaled $1.7 billion. Structural Considerations Since Southern Company and Southern Company Gas are holding companies, the right of Southern Company and Southern Company Gas and, hence, the right of creditors of Southern Company or Southern Company Gas to participate in any distribution of the assets of any respective subsidiary of Southern Company or Southern Company Gas, whether upon liquidation, reorganization or otherwise, is subject to prior claims of creditors and preferred stockholders of such subsidiary. Southern Company Gas' 100%-owned subsidiary, Southern Company Gas Capital, was established to provide for certain of Southern Company Gas' ongoing financing needs through a commercial paper program, the issuance of various debt, hybrid securities, and other financing arrangements. Southern Company Gas fully and unconditionally guarantees all debt issued by Southern Company Gas Capital. Nicor Gas is not permitted by regulation to make loans to affiliates or utilize Southern Company Gas Capital for its financing needs. Southern Power Company's senior notes, bank term loan, commercial paper, and bank credit arrangement are unsecured senior indebtedness, which rank equally with all other unsecured and unsubordinated debt of Southern Power Compan y. Southern Power's subsidiaries are not issuers, borrowers, or obligors, as applicable, under any of these unsecured senior debt arrangements, which are effectively subordinated to any future secured debt of Southern Power Company and any potential claims of creditors of Southern Power's subsidiaries. 9. LEASES Lessee The Registrants recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with ROU assets that will be amortized over the term of each lease. As lessee, the Registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
At December 31, 2023 |  |  |  |  |  |
Electric generating units(*) | $ 670 | $ 58 | $ 1,028 | $ — | $ — | $ —
Real estate/land | 871 | 4 | 54 | 2 | 546 | 28
Communication towers | 123 | 1 | 4 | — | — | 23
Railcars | 64 | 32 | 27 | 5 | — | —
Other | 60 | 3 | 2 | 18 | — | —
Total | $ 1,788 | $ 98 | $ 1,115 | $ 25 | $ 546 | $ 51
At December 31, 2022 |  |  |  |  |  |
Electric generating units(*) | $ 760 | $ 59 | $ 1,163 | $ — | $ — | $ —
Real estate/land | 885 | 4 | 54 | 2 | 542 | 36
Communication towers | 141 | 2 | 4 | — | — | 23
Railcars | 34 | 12 | 18 | 3 | — | —
Other | 79 | 4 | 1 | 21 | — | 1
Total | $ 1,899 | $ 81 | $ 1,240 | $ 26 | $ 542 | $ 60
*Amounts related to affiliate leases are eliminated in consolidation for Southern Company. See "Contracts that Contain a Lease" herein for additional information. Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 27 years while the land leases have remaining terms of up to 44 years, including renewal periods. Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies and Nicor Gas. Communication tower leases have remaining terms of up to 17 years. Renewal options exist in many of the leases. The expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease unless it is considered reasonably certain that the lease will be extended. Land leases associated with renewable energy facilities at Southern Power and communication tower leases for automated meter infrastructure at Nicor Gas include renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities and the automated meter infrastructure, respectively. Contracts that Contain a Lease While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the PPA, which varies between one and 16 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of $416 million and $461 million at December 31, 2023 and 2022, respectively. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as reviewed and approved by the Georgia PSC. Amounts related to the affiliate PPAs are eliminated in consolidation for Southern Company. Short-term Leases Leases with an initial term of 12 months or less are not recorded on the balance sheet; the Registrants generally recognize lease expense for these leases on a straight-line basis over the lease term. Residual Value Guarantees Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial at December 31, 2023 and 2022. Lease and Nonlease Components For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the Registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset. Balance sheet amounts recorded for operating and finance leases are as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
At December 31, 2023 |  |  |  |  |  |
Operating Leases |  |  |  |  |  |
Operating lease ROU assets, net | $ 1,432 | $ 87 | $ 884 | $ 9 | $ 488 | $ 47
Operating lease obligations - current | $ 183 | $ 12 | $ 135 | $ 3 | $ 29 | $ 11
Operating lease obligations - non-current | 1,307 | 81 | 740 | 6 | 517 | 40
Total operating lease obligations(*) | $ 1,490 | $ 93 | $ 875 | $ 9 | $ 546 | $ 51
Finance Leases |  |  |  |  |  |
Finance lease ROU assets, net | $ 272 | $ 5 | $ 203 | $ 15 | $ — | $ —
Finance lease obligations - current | $ 11 | $ 2 | $ 18 | $ 1 | $ — | $ —
Finance lease obligations - non-current | 287 | 3 | 222 | 15 | — | —
Total finance lease obligations | $ 298 | $ 5 | $ 240 | $ 16 | $ — | $ —
At December 31, 2022 |  |  |  |  |  |
Operating Leases |  |  |  |  |  |
Operating lease ROU assets, net | $ 1,531 | $ 71 | $ 1,007 | $ 9 | $ 489 | $ 57
Operating lease obligations - current | $ 197 | $ 9 | $ 151 | $ 4 | $ 28 | $ 9
Operating lease obligations - non-current | 1,388 | 67 | 851 | 5 | 514 | 51
Total operating lease obligations(*) | $ 1,585 | $ 76 | $ 1,002 | $ 9 | $ 542 | $ 60
Finance Leases |  |  |  |  |  |
Finance lease ROU assets, net | $ 292 | $ 5 | $ 205 | $ 16 | $ — | $ —
Finance lease obligations - current | $ 18 | $ 2 | $ 16 | $ 1 | $ — | $ —
Finance lease obligations - non-current | 296 | 3 | 222 | 16 | — | —
Total finance lease obligations | $ 314 | $ 5 | $ 238 | $ 17 | $ — | $ —
*Includes operating lease obligations related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $566 million, $58 million, and $813 million, respectively, at December 31, 2023 and $652 million, $59 million, and $952 million, respectively, at December 31, 2022. If not presented separately on the Registrants' balance sheets, amounts related to leases are presented as follows: operating lease ROU assets, net are included in "other deferred charges and assets"; operating lease obligations are included in "other current liabilities" and "other deferred credits and liabilities," as applicable; finance lease ROU assets, net are included in "plant in service"; and finance lease obligations are included in "securities due within one year" and "long-term debt," as applicable. Lease costs for 2023, 2022, and 2021, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |
Lease cost |  |  |  |  |  |
Operating lease cost(*) | $ 252 | $ 16 | $ 192 | $ 5 | $ 34 | $ 12
Finance lease cost: |  |  |  |  |  |
Amortization of ROU assets | 24 | 2 | 19 | 1 | — | —
Interest on lease obligations | 14 | — | 17 | — | — | —
Total finance lease cost | 38 | 2 | 36 | 1 | — | —
Short-term lease costs | 40 | 16 | 16 | — | — | —
Variable lease cost | 47 | — | 74 | — | 4 | —
Sublease income | — | — | — | — | — | —
Total lease cost | $ 377 | $ 34 | $ 318 | $ 6 | $ 38 | $ 12
2022 |  |  |  |  |  |
Lease cost |  |  |  |  |  |
Operating lease cost(*) | $ 297 | $ 59 | $ 198 | $ 5 | $ 32 | $ 15
Finance lease cost: |  |  |  |  |  |
Amortization of ROU assets | 23 | 1 | 15 | 1 | — | —
Interest on lease obligations | 13 | — | 17 | 1 | — | —
Total finance lease cost | 36 | 1 | 32 | 2 | — | —
Short-term lease costs | 64 | 44 | 13 | — | — | —
Variable lease cost | 125 | 13 | 105 | — | 5 | —
Sublease income | (1) | — | — | — | — | —
Total lease cost | $ 521 | $ 117 | $ 348 | $ 7 | $ 37 | $ 15
2021 |  |  |  |  |  |
Lease cost |  |  |  |  |  |
Operating lease cost(*) | $ 313 | $ 58 | $ 208 | $ 2 | $ 33 | $ 19
Finance lease cost: |  |  |  |  |  |
Amortization of ROU assets | 21 | 1 | 11 | 1 | — | —
Interest on lease obligations | 11 | — | 16 | 1 | — | —
Total finance lease cost | 32 | 1 | 27 | 2 | — | —
Short-term lease costs | 48 | 15 | 24 | — | — | —
Variable lease cost | 96 | 4 | 83 | — | 5 | —
Sublease income | 1 | — | — | — | — | —
Total lease cost | $ 490 | $ 78 | $ 342 | $ 4 | $ 38 | $ 19
*Includes operating lease costs related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $112 million, $4 million, and $174 million, respectively, in 2023, $162 million, $48 million, and $180 million, respectively, in 2022, and $165 million, $47 million, and $184 million, respectively, in 2021. Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs, including $42 million, $45 million, and $41 million in 2023, 2022, and 2021, respectively, from finance leases which are included in purchased power on Georgia Power's statements of income, of which $21 million, $21 million, and $20 million was included in purchased power, affiliates in 2023, 2022, and 2021, respectively. Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |  |
Other information |  |  |  |  |  |
Cash paid for amounts included in the measurements of lease obligations: |  |  |  |  |  |
Operating cash flows from operating leases | $ 253 | $ 17 | $ 199 | $ 5 | $ 33 | $ 12
Operating cash flows from finance leases | 15 | — | 22 | — | — | —
Financing cash flows from finance leases | 18 | 2 | 16 | 1 | — | —
ROU assets obtained under operating leases | 100 | 30 | 26 | 1 | 7 | 7
ROU assets obtained under finance leases | 3 | 3 | 18 | — | — | —
2022 |  |  |  |  |  |
Other information |  |  |  |  |  |
Cash paid for amounts included in the measurements of lease obligations: |  |  |  |  |  |
Operating cash flows from operating leases | $ 303 | $ 58 | $ 206 | $ 5 | $ 30 | $ 14
Operating cash flows from finance leases | 11 | — | 20 | 1 | — | —
Financing cash flows from finance leases | 16 | 1 | 10 | 1 | — | —
ROU assets obtained under operating leases | 56 | 10 | 17 | 9 | — | 3
Reassessment of ROU assets under operating leases | 16 | — | — | — | 16 | —
ROU assets obtained under finance leases | 118 | 2 | 116 | — | — | —
2021 |  |  |  |  |  |
Other information |  |  |  |  |  |
Cash paid for amounts included in the measurements of lease obligations: |  |  |  |  |  |
Operating cash flows from operating leases | $ 308 | $ 58 | $ 211 | $ 2 | $ 28 | $ 19
Operating cash flows from finance leases | 9 | — | 17 | 1 | — | —
Financing cash flows from finance leases | 17 | 1 | 9 | 1 | — | —
ROU assets obtained under operating leases | 64 | 3 | 9 | — | 72 | 7
ROU assets obtained under finance leases | 3 | — | — | — | — | —
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
At December 31, 2023 |  |  |  |  |  |
Weighted-average remaining lease term in years: |  |  |  |  |  |
Operating leases | 17.2 | 11.1 | 7.5 | 4.6 | 33.1 | 7.0
Finance leases | 16.7 | 4.3 | 10.6 | 11.9 | N/A | N/A
Weighted-average discount rate: |  |  |  |  |  |
Operating leases | 4.68 % | 5.02 % | 4.58 % | 3.67 % | 4.89 % | 3.80 %
Finance leases | 4.85 % | 3.93 % | 5.95 % | 2.74 % | N/A | N/A
At December 31, 2022 |  |  |  |  |  |
Weighted-average remaining lease term in years: |  |  |  |  |  |
Operating leases | 17.3 | 13.0 | 8.1 | 4.7 | 34.0 | 11.0
Finance leases | 17.4 | 6.4 | 11.8 | 12.9 | N/A | N/A
Weighted-average discount rate: |  |  |  |  |  |
Operating leases | 4.51 % | 4.87 % | 4.52 % | 3.49 % | 4.86 % | 3.79 %
Finance leases | 4.87 % | 3.00 % | 8.06 % | 2.74 % | N/A | N/A
Maturities of lease liabilities are as follows:
| At December 31, 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Maturity Analysis |  |  |  |  |  |
Operating leases: |  |  |  |  |  |
2024 | $ 230 | $ 16 | $ 172 | $ 4 | $ 36 | $ 12
2025 | 203 | 14 | 147 | 3 | 29 | 12
2026 | 180 | 12 | 142 | 2 | 29 | 9
2027 | 159 | 10 | 141 | — | 29 | 4
2028 | 143 | 7 | 135 | — | 30 | 3
Thereafter | 1,378 | 64 | 303 | 1 | 1,000 | 18
Total | 2,293 | 123 | 1,040 | 10 | 1,153 | 58
Less: Present value discount | 803 | 30 | 165 | 1 | 607 | 7
Operating lease obligations | $ 1,490 | $ 93 | $ 875 | $ 9 | $ 546 | $ 51
Finance leases: |  |  |  |  |  |
2024 | $ 22 | $ 2 | $ 27 | $ 2 | $ — | $ —
2025 | 27 | 1 | 36 | 2 | — | —
2026 | 27 | 1 | 36 | 2 | — | —
2027 | 27 | 1 | 36 | 2 | — | —
2028 | 26 | 1 | 37 | 1 | — | —
Thereafter | 320 | — | 153 | 10 | — | —
Total | 449 | 6 | 325 | 19 | — | —
Less: Present value discount | 151 | 1 | 85 | 3 | — | —
Finance lease obligations | $ 298 | $ 5 | $ 240 | $ 16 | $ — | $ —
Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. Lessor The Registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable Registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to 10 years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include a tolling arrangement related to an electric generating unit accounted for as a sales-type lease with a remaining term of 15 years. For Southern Power, these arrangements consist of PPAs related to electric generating units accounted for as operating leases with remaining terms of up to 23 years and PPAs related to battery energy storage facilities accounted for as sales-type leases with remaining terms of up to 18 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 19 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with remaining terms of up to 10 years. Lease income for 2023, 2022, and 2021, is as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |  |
Lease income - interest income on sales-type leases | $ 24 | $ — | $ — | $ 14 | $ 10 | $ —
Lease income - operating leases | 164 | 35 | 29 | 2 | 85 | 37
Variable lease income | 406 | 1 | — | — | 437 | —
Total lease income | $ 594 | $ 36 | $ 29 | $ 16 | $ 532 | $ 37
2022 |  |  |  |  |  |
Lease income - interest income on sales-type leases | $ 25 | $ — | $ — | $ 15 | $ 10 | $ —
Lease income - operating leases | 208 | 77 | 32 | 2 | 85 | 36
Variable lease income | 417 | 1 | — | — | 448 | —
Total lease income | $ 650 | $ 78 | $ 32 | $ 17 | $ 543 | $ 36
2021 |  |  |  |  |  |
Lease income - interest income on sales-type leases | $ 15 | $ — | $ — | $ 14 | $ 1 | $ —
Lease income - operating leases | 223 | 82 | 42 | 2 | 85 | 35
Variable lease income | 429 | — | — | — | 456 | —
Total lease income | $ 667 | $ 82 | $ 42 | $ 16 | $ 542 | $ 35
Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income related to PPAs for Alabama Power and Southern Power is included in wholesale revenues. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses. Mississippi Power has a tolling arrangement accounted for as a sales-type lease. During 2021, Mississippi Power completed construction of additional leased assets under the lease and, upon completion, the book value of $39 million was transferred from CWIP to lease receivables. The transfer represented a non-cash investing transaction for purposes of the statements of cash flows. During 2021, Southern Power completed construction of a portion of the Garland and Tranquillity battery energy storage facilities' assets and recorded losses totaling $40 million upon commencement of the related PPAs, which Southern Power accounts for as sales-type leases. The losses were due to ITCs retained and expected to be realized by Southern Power and its partners in these projects, and no estimated residual asset value was assumed in calculating the losses. Each lease had an initial term of 20 years. Upon commencement of the leases, the book values of the related assets totaling $210 million were derecognized from CWIP and lease receivables were recorded. The transfers represented noncash investing transactions for purposes of the statement of cash flows. See Note 15 under "Southern Power" for additional information. The undiscounted cash flows expected to be received for in-service leased assets under the leases are as follows:
| At December 31, 2023
| Southern Company | Mississippi Power | Southern Power
| (in millions)
2024 | $ 38 | $ 23 | $ 15
2025 | 37 | 22 | 15
2026 | 36 | 21 | 15
2027 | 35 | 20 | 15
2028 | 34 | 19 | 15
Thereafter | 330 | 145 | 185
Total undiscounted cash flows | $ 510 | $ 250 | $ 260
Net investment in sales-type lease(*) | 311 | 148 | 163
Difference between undiscounted cash flows and discounted cash flows | $ 199 | $ 102 | $ 97
*For Mississippi Power, included in other current assets and other property and investments on the balance sheets. For Southern Power, included in other current assets ($15 million and $15 million at December 31, 2023 and 2022, respectively) and net investment in sales-type leases ($148 million and $154 million at December 31, 2023 and 2022, respectively) on the balance sheet. The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases are as follows:
| At December 31, 2023
| Southern Company | Alabama Power | Southern Power | Southern Company Gas
| (in millions)
2024 | $ 116 | $ 7 | $ 90 | $ 35
2025 | 107 | 5 | 75 | 29
2026 | 108 | 5 | 73 | 29
2027 | 105 | 4 | 75 | 28
2028 | 104 | 3 | 76 | 28
Thereafter | 706 | 26 | 91 | 354
Total | $ 1,246 | $ 50 | $ 480 | $ 503
Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Alabama Power and Southern Power allocate revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Georgia Power and Mississippi Power are immaterial. Southern Company Leveraged Lease At December 31, 2020, a subsidiary of Southern Holdings had four leveraged lease agreements related to energy generation, distribution, and transportation assets, including two domestic and two international projects. During 2021, one of the domestic projects was sold and the agreements for both international projects were terminated. At December 31, 2023, the one remaining leveraged lease agreement, which relates to energy generation, had an expected remaining term of eight years. Southern Company continues to receive federal income tax deductions for depreciation and amortization, as well as interest on long-term debt related to this investment. Southern Company wrote off the related investment balance in 2020 following an evaluation of the recoverability of the lease receivable and the expected residual value of the generation assets at the end of the lease. The following table provides a summary of the components of income related to leveraged lease investments. Income was impacted in 2021 by the impairment charges discussed below and in Note 15 under "Southern Company." Income in 2021 does not include the impacts of the sale and terminations of leveraged lease projects discussed in Note 15 under "Southern Company."
| 2021
| (in millions)
Pretax leveraged lease income | $ 17
Income tax expense | (5)
Net leveraged lease income | $ 12
In June 2022, the Southern Holdings subsidiary operating the generating plant for the lessee provided notice to the lessee to terminate the related operating and maintenance agreement effective June 30, 2023. Subsequently, the lessee failed to make the semi-annual lease payment due in December 2022. As a result, the Southern Holdings subsidiary was unable to make its corresponding payment to the holders of the underlying non-recourse debt related to the generation assets. The parties to the lease entered into forbearance agreements which suspended the related contractual rights of the parties while they continued restructuring negotiations, during which the termination date for the operating and maintenance agreement was delayed until July 31, 2023. The negotiations were completed on July 14, 2023, resulting in the Southern Holdings subsidiary agreeing to continue operating the plant for the lessee until the lessee's associated power off-take agreement ends in 2032, subject to certain terms and conditions. The restructuring had no material impact on Southern Company's financial statements. Southern Company will continue to monitor the operational performance of the underlying assets and evaluate the ability of the lessee to continue to meet its obligations, including those associated with a future closure or retirement of the generation assets and associated properties, including the dry ash landfill. 10. INCOME TAXES Southern Company files a consolidated federal income tax return and the Registrants file various state income tax returns, some of which are combined or unitary. Under a joint consolidated income tax allocation agreement, each Southern Company subsidiary's current and deferred tax expense is computed on a stand-alone basis, and each subsidiary is allocated an amount of tax similar to that which would be paid if it filed a separate income tax return. In accordance with IRS regulations, each company is jointly and severally liable for the federal tax liability. Current and Deferred Income Taxes Details of income tax provisions are as follows:
| 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Federal — |  |  |  |  |  |
Current | $ 54 | $ 242 | $ 205 | $ 49 | $ (320) | $ 62
Deferred | 299 | (257) | 195 | (26) | 334 | 68
Total federal | 353 | (15) | 400 | 23 | 14 | 130
State — |  |  |  |  |  |
Current | 41 | 82 | 37 | 1 | (1) | 24
Deferred | 102 | 14 | 11 | 12 | (1) | 57
Total state | 143 | 96 | 48 | 13 | (2) | 81
Total | $ 496 | $ 81 | $ 448 | $ 36 | $ 12 | $ 211
| 2022
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Federal — |  |  |  |  |  |
Current | $ 10 | $ 54 | $ 38 | $ 42 | $ (43) | $ 122
Deferred | 455 | 259 | 152 | (16) | 56 | (3)
Total federal | 465 | 313 | 190 | 26 | 13 | 119
State — |  |  |  |  |  |
Current | 27 | 14 | (21) | — | 2 | 42
Deferred | 303 | 96 | 201 | 11 | 5 | 19
Total state | 330 | 110 | 180 | 11 | 7 | 61
Total | $ 795 | $ 423 | $ 370 | $ 37 | $ 20 | $ 180
| 2021
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Federal — |  |  |  |  |  |
Current | $ 50 | $ 104 | $ 311 | $ 25 | $ (340) | $ 85
Deferred | 36 | 172 | (449) | (15) | 343 | 35
Total federal | 86 | 276 | (138) | 10 | 3 | 120
State — |  |  |  |  |  |
Current | (25) | 23 | 71 | — | (16) | (68)
Deferred | 206 | 73 | (101) | 11 | — | 223
Total state | 181 | 96 | (30) | 11 | (16) | 155
Total | $ 267 | $ 372 | $ (168) | $ 21 | $ (13) | $ 275
Southern Company's and Southern Power's ITCs and PTCs generated in the current tax year and carried forward from prior tax years that cannot be utilized in the current tax year are reclassified from current to deferred taxes in federal income tax expense in the tables above. Southern Power's ITCs and PTCs reclassified in this manner include $5 million for 2023, $17 million for 2022, and $6 million for 2021. Southern Power received $332 million, $49 million, and $289 million of cash related to federal ITCs under renewable energy initiatives in 2023, 2022, and 2021, respectively. See "Deferred Tax Assets and Liabilities" herein for additional information. In accordance with regulatory requirements, deferred federal ITCs for the traditional electric operating companies are amortized over the average life of the related property, with such amortization normally applied as a credit to reduce depreciation and amortization in the statements of income. Southern Power's and the natural gas distribution utilities' deferred federal ITCs, as well as certain state ITCs for Nicor Gas, are amortized to income tax expense over the life of the respective asset. ITCs amortized in 2023, 2022, and 2021 were immaterial for the traditional electric operating companies and Southern Company Gas and were as follows for Southern Company and Southern Power:
| Southern Company | Southern Power
| (in millions)
2023 | $ 84 | $ 58
2022 | 83 | 58
2021 | 84 | 58
When Southern Power recognizes tax credits, the tax basis of the asset is reduced by 50% of the ITCs received, resulting in a net deferred tax asset. Southern Power has elected to recognize the tax benefit of this basis difference as a reduction to income tax expense in the year in which the plant reaches commercial operation. State ITCs and other state credits, which are recognized in the period in which the credits are generated, reduced Georgia Power's income tax expense by $49 million in 2023, $53 million in 2022, and $66 million in 2021. Southern Power's federal and state PTCs, which are recognized in the period in which the credits are generated, reduced Southern Power's income tax expense by $26 million in 2023, $27 million in 2022, and $16 million in 2021. During the fourth quarter 2023, Southern Power executed an agreement to transfer certain PTCs generated in 2023 and received cash of $12 million. The discount recognized was booked through income tax expense and was immaterial. Pursuant to the Global Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 under "Georgia Power – Nuclear Construction – Joint Owner Contracts"), Georgia Power paid $39 million to the other Vogtle Owners for advanced nuclear PTCs for Plant Vogtle Unit 3. The gain recognized in 2023 was booked through income tax benefit and was immaterial. Effective Tax Rate Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power. In July 2021, Southern Company Gas affiliates completed the sale of Sequent. As a result of the sale, changes in state apportionment rates resulted in $85 million of additional net state tax expense. See Note 15 under "Southern Company Gas" for additional information. A reconciliation of the federal statutory income tax rate to the effective income tax rate is as follows:
| 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Federal statutory rate | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 %
State income tax, net of federal deduction | 2.6 | 5.2 | 1.5 | 4.9 | (0.7) | 7.8
Employee stock plans' dividend deduction | (0.5) | — | — | — | — | —
Non-deductible book depreciation | 0.7 | 0.7 | 0.8 | 0.4 | — | —
Flowback of excess deferred income taxes | (9.2) | (19.8) | (2.6) | (10.2) | — | (2.6)
AFUDC-Equity | (1.1) | (1.2) | (1.2) | — | — | —
Federal PTCs | (1.2) | — | (1.4) | — | (7.4) | —
ITC amortization | (1.3) | (0.1) | (0.1) | — | (19.0) | —
Noncontrolling interests | 0.6 | — | — | — | 11.1 | —
Other | (0.2) | (0.2) | (0.3) | 0.1 | 0.1 | (0.6)
Effective income tax (benefit) rate | 11.4 % | 5.6 % | 17.7 % | 16.2 % | 5.1 % | 25.6 %
| 2022
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Federal statutory rate | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 %
State income tax, net of federal deduction | 6.2 | 4.8 | 6.5 | 4.4 | 1.9 | 6.4
Employee stock plans' dividend deduction | (0.5) | — | — | — | — | —
Non-deductible book depreciation | 0.6 | 0.5 | 0.6 | 0.3 | — | —
Flowback of excess deferred income taxes | (6.6) | (1.9) | (9.6) | (7.8) | — | (2.5)
AFUDC-Equity | (1.1) | (0.8) | (1.5) | — | — | —
Federal PTCs | — | — | — | — | (6.6) | —
ITC amortization | (1.3) | (0.1) | (0.1) | — | (17.2) | (0.1)
Noncontrolling interests | 0.5 | — | — | — | 8.4 | —
Other | — | 0.3 | — | 0.3 | (0.1) | (0.9)
Effective income tax (benefit) rate | 18.8 % | 23.8 % | 16.9 % | 18.2 % | 7.4 % | 23.9 %
| 2021
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Federal statutory rate | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 % | 21.0 %
State income tax, net of federal deduction | 5.5 | 4.6 | (5.7) | 4.9 | (8.0) | 15.1
Employee stock plans' dividend deduction | (0.9) | — | — | — | — | —
Non-deductible book depreciation | 0.9 | 0.5 | 3.1 | 0.4 | — | —
Flowback of excess deferred income taxes | (11.7) | (2.6) | (49.9) | (15.2) | — | (2.8)
AFUDC-Equity | (1.5) | (0.7) | (6.4) | — | — | —
Federal PTCs | — | — | — | — | (4.6) | —
ITC amortization | (2.2) | (0.1) | (0.4) | — | (29.7) | (0.1)
Noncontrolling interests | 0.8 | — | — | — | 13.4 | —
Leveraged lease impairments and dispositions | (1.4) | — | — | — | — | —
Other | (0.1) | 0.2 | (1.9) | 0.6 | (0.4) | 0.6
Effective income tax (benefit) rate | 10.4 % | 22.9 % | (40.2) % | 11.7 % | (8.3) % | 33.8 %
Deferred Tax Assets and Liabilities The tax effects of temporary differences between the carrying amounts of assets and liabilities in the financial statements of the Registrants and their respective tax bases, which give rise to deferred tax assets and liabilities, are as follows:
| December 31, 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Deferred tax liabilities — |  |  |  |  |  |
Accelerated depreciation | $ 9,683 | $ 2,566 | $ 3,628 | $ 339 | $ 1,346 | $ 1,576
Property basis differences | 2,647 | 1,444 | 812 | 188 | — | 189
Employee benefit obligations | 979 | 321 | 446 | 49 | 12 | 74
AROs | 833 | 476 | 314 | — | — | —
Under recovered fuel and natural gas costs | 601 | 80 | 508 | 13 | — | —
Regulatory assets – |  |  |  |  |  |
AROs | 1,902 | 667 | 1,196 | 39 | — | —
Employee benefit obligations | 797 | 213 | 260 | 37 | — | 11
Remaining book value of retired assets | 369 | 143 | 221 | 5 | — | —
Premium on reacquired debt | 63 | 9 | 53 | 1 | — | —
Other | 700 | 182 | 223 | 43 | 2 | 191
Total deferred income tax liabilities | 18,574 | 6,101 | 7,661 | 714 | 1,360 | 2,041
Deferred tax assets — |  |  |  |  |  |
AROs | 2,735 | 1,143 | 1,510 | 39 | — | —
ITC and PTC carryforwards | 1,387 | 12 | 691 | — | 481 | —
Employee benefit obligations | 985 | 224 | 316 | 52 | 10 | 89
Estimated loss on plants under construction | 857 | — | 857 | — | — | —
Estimated loss on regulatory disallowance | 26 | — | — | — | — | 26
Other state deferred tax attributes | 363 | — | 13 | 231 | 49 | 8
Federal effect of net state deferred tax liabilities | 418 | 215 | 92 | — | 27 | 101
Other property basis differences | 197 | — | 83 | — | 97 | —
State effect of federal deferred taxes | 115 | 115 | — | — | — | —
Other partnership basis differences | 85 | — | — | — | 85 | —
Regulatory liability associated with the Tax Reform Legislation (not subject to normalization) | 34 | 30 | — | 3 | — | —
Long-term debt fair value adjustment | 79 | — | — | — | — | 79
Other comprehensive losses | 67 | 4 | 4 | — | 6 | —
Other | 538 | 188 | 152 | 57 | 18 | 74
Total deferred income tax assets | 7,886 | 1,931 | 3,718 | 382 | 773 | 377
Valuation allowance | (206) | — | (75) | (41) | (27) | (7)
Net deferred income tax assets | 7,680 | 1,931 | 3,643 | 341 | 746 | 370
Net deferred income taxes (assets)/liabilities | $ 10,894 | $ 4,170 | $ 4,018 | $ 373 | $ 614 | $ 1,671
Recognized in the balance sheets: |  |  |  |  |  |
Accumulated deferred income taxes – assets | $ (96) | $ — | $ — | $ (96) | $ — | $ —
Accumulated deferred income taxes – liabilities | $ 10,990 | $ 4,170 | $ 4,018 | $ 469 | $ 614 | $ 1,671
| December 31, 2022
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Deferred tax liabilities — |  |  |  |  |  |
Accelerated depreciation | $ 9,443 | $ 2,564 | $ 3,447 | $ 338 | $ 1,351 | $ 1,505
Property basis differences | 2,350 | 1,303 | 693 | 179 | — | 150
Employee benefit obligations | 888 | 284 | 412 | 43 | 11 | 68
AROs | 876 | 499 | 324 | — | — | —
Under recovered fuel and natural gas costs | 805 | 185 | 548 | 40 | — | 32
Regulatory assets – |  |  |  |  |  |
AROs | 2,006 | 679 | 1,285 | 42 | — | —
Employee benefit obligations | 677 | 180 | 226 | 30 | — | 15
Remaining book value of retired assets | 400 | 142 | 253 | 5 | — | —
Premium on reacquired debt | 66 | 9 | 57 | — | — | —
Other | 555 | 179 | 181 | 40 | 14 | 82
Total deferred income tax liabilities | 18,066 | 6,024 | 7,426 | 717 | 1,376 | 1,852
Deferred tax assets — |  |  |  |  |  |
AROs | 2,882 | 1,178 | 1,609 | 42 | — | —
ITC and PTC carryforwards | 1,685 | 12 | 673 | — | 794 | —
Employee benefit obligations | 890 | 198 | 304 | 47 | 9 | 89
Estimated loss on plants under construction | 888 | — | 888 | — | — | —
Other state deferred tax attributes | 388 | — | 12 | 239 | 51 | 7
Federal effect of net state deferred tax liabilities | 365 | 175 | 88 | — | 28 | 92
Other property basis differences | 207 | — | 79 | — | 109 | —
State effect of federal deferred taxes | 136 | 136 | — | — | — | —
Other partnership basis differences | 111 | — | — | — | 111 | —
Regulatory liability associated with the Tax Reform Legislation (not subject to normalization) | 137 | 127 | — | 9 | — | —
Long-term debt fair value adjustment | 85 | — | — | — | — | 85
Other comprehensive losses | 72 | 4 | 5 | — | 5 | —
Other | 552 | 213 | 186 | 62 | 17 | 28
Total deferred income tax assets | 8,398 | 2,043 | 3,844 | 399 | 1,124 | 301
Valuation allowance | (257) | — | (125) | (41) | (27) | (9)
Net deferred income tax assets | 8,141 | 2,043 | 3,719 | 358 | 1,097 | 292
Net deferred income taxes (assets)/liabilities | $ 9,925 | $ 3,981 | $ 3,707 | $ 359 | $ 279 | $ 1,560
Recognized in the balance sheets: |  |  |  |  |  |
Accumulated deferred income taxes – assets | $ (111) | $ — | $ — | $ (107) | $ — | $ —
Accumulated deferred income taxes – liabilities | $ 10,036 | $ 3,981 | $ 3,707 | $ 466 | $ 279 | $ 1,560
The traditional electric operating companies and the natural gas distribution utilities have tax-related regulatory assets (deferred income tax charges) and regulatory liabilities (deferred income tax credits). The regulatory assets are primarily attributable to tax benefits flowed through to customers in prior years, deferred taxes previously recognized at rates lower than the current enacted tax law, and taxes applicable to capitalized interest. The regulatory liabilities are primarily attributable to deferred taxes previously recognized at rates higher than the current enacted tax law and to unamortized ITCs. See Note 2 for each Registrant's related balances at December 31, 2023 and 2022. Tax Credit Carryforwards Federal ITC/PTC carryforwards at December 31, 2023 were as follows:
| Southern Company | Alabama Power | Georgia Power | Southern Power
| (in millions)
Federal ITC/PTC carryforwards | $ 829 | $ 12 | $ 131 | $ 481
Tax year in which federal ITC/PTC carryforwards begin expiring | 2031 | 2032 | 2031 | 2035
Year by which federal ITC/PTC carryforwards are expected to be utilized | 2029 | 2028 | 2028 | 2029
The estimated tax credit utilization reflects the various transactions described in Note 15 and could be impacted by numerous factors, including the acquisition of additional renewable projects, changes in taxable income projections, transfer of eligible credits, potential income tax rate changes, and the ultimate implementation of the natural gas safe harbor method for repairs. In the third quarter 2023, Georgia Power started generating advanced nuclear PTCs for Plant Vogtle Unit 3 beginning on the in-service date of July 31, 2023. In addition, pursuant to the Global Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 under "Georgia Power – Nuclear Construction – Joint Owner Contracts"), Georgia Power is purchasing advanced nuclear PTCs for Plant Vogtle Unit 3 from the other Vogtle Owners. See Note 2 under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4. At December 31, 2023, Georgia Power also had approximately $452 million in net state investment and other net state tax credit carryforwards for the State of Georgia that will expire between tax years 2023 and 2032 and are not expected to be fully utilized. Georgia Power has a net state valuation allowance of $60 million associated with these carryforwards. The ultimate outcome of these matters cannot be determined at this time. Net Operating Loss Carryforwards At December 31, 2023, the net state income tax benefit of state and local NOL carryforwards for Southern Company's subsidiaries were as follows:
Company/Jurisdiction | Approximate Net State Income Tax Benefit of NOL Carryforwards | Tax Year NOL Begins Expiring
| (in millions) |
Mississippi Power |  |
Mississippi | $ 183 | 2032
Southern Power |  |
Oklahoma | 26 | 2035
Florida | 10 | 2034
Other states | 2 | Various
Southern Power Total | $ 38 |
Other(*) |  |
New York | 11 | 2036
New York City | 14 | 2036
Other states | 30 | Various
Southern Company Total | $ 276 |
*Represents other non-registrant Southern Company subsidiaries. Alabama Power, Georgia Power, and Southern Company Gas did not have material state or local NOL carryforwards at December 31, 2023. State NOLs for Mississippi, Oklahoma, and Florida are not expected to be fully utilized prior to expiration. At December 31, 2023, Mississippi Power had a net state valuation allowance of $32 million for the Mississippi NOL, Southern Power had net state valuation allowances of $11 million for the Oklahoma NOL and $10 million for the Florida NOL, and Southern Company had a net valuation allowance of $25 million for the New York and New York City NOLs. The ultimate outcome of these matters cannot be determined at this time. Unrecognized Tax Benefits Changes in unrecognized tax benefits for the periods presented were as follows:
| Southern Company | Georgia Power | Southern Company Gas
| (in millions)
Unrecognized tax benefits at December 31, 2020 | $ 44 | $ — | $ —
Tax positions changes – |  |  |
Increase from prior periods | 3 | — | —
Unrecognized tax benefits at December 31, 2021 | 47 | — | —
Tax positions changes – |  |  |
Increase from prior periods | 33 | — | 32
Unrecognized tax benefits at December 31, 2022 | 80 | — | 32
Tax positions changes – |  |  |
Increase from prior periods | 88 | 86 | 2
Statute of limitations expiration | (52) | (9) | —
Unrecognized tax benefits at December 31, 2023 | $ 116 | $ 77 | $ 34
The unrecognized tax positions increase from prior periods for 2022 is primarily related to the amendment of certain 2018 state tax filing positions related to Southern Company Gas dispositions. If accepted by the states, these positions would decrease Southern Company's and Southern Company Gas' annual effective tax rates. The ultimate outcome of these unrecognized tax benefits is dependent on acceptance by each state and is not expected to be resolved within the next 12 months. The unrecognized tax positions increase from prior periods for 2023 are primarily related to the amendment of certain 2019 through 2021 state tax filing positions related to tax credit utilization, a portion of which decreased in the fourth quarter 2023 due to a statute of limitations expiration. If effective settlement of the positions is favorable, these positions would decrease Southern Company's and Georgia Power's annual effective tax rates. The ultimate outcome of this unrecognized tax benefit, of which a portion is expected to be resolved within the next 12 months, is dependent on acceptance by the state or expiration of related statute of limitations. The unrecognized tax positions reductions due to statute of limitations expiration for 2023 primarily relates to a 2019 state tax filing position to exclude certain gains from 2019 dispositions from taxation in a certain unitary state. This tax position and related interest was recognized in the fourth quarter 2023 and decreased Southern Company's annual effective tax rate. All of the Registrants classify interest on tax uncertainties as interest expense. Accrued interest for all tax positions was immaterial for all years presented. None of the Registrants accrued any penalties on uncertain tax positions. The IRS has finalized its audits of Southern Company's consolidated federal income tax returns through 2022. Southern Company is a participant in the Compliance Assurance Process of the IRS. The IRS has selected six Southern Power partnership returns for exam for the 2020 and 2021 tax years. The ultimate outcome of this matter cannot be determined at this time. The audits for the Registrants' state income tax returns have either been concluded, or the statute of limitations has expired, for years prior to 2015. 11. RETIREMENT BENEFITS The Southern Company system has a qualified defined benefit, trusteed pension plan covering substantially all employees, with the exception of PowerSecure employees. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). No contributions to the qualified pension plan were made for the year ended December 31, 2023 and no mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2024. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses. For the year ending December 31, 2024, no contributions to any other postretirement trusts are expected. Actuarial Assumptions The weighted average rates assumed in the actuarial calculations used to determine both the net periodic costs for the pension and other postretirement benefit plans for the following year and the benefit obligations as of the measurement date are presented below.
| 2023
Assumptions used to determine net periodic costs: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Pension plans |  |  |  |  |  |
Discount rate – benefit obligations | 5.25 % | 5.26 % | 5.25 % | 5.25 % | 5.31 % | 5.24 %
Discount rate – interest costs | 5.13 | 5.14 | 5.12 | 5.12 | 5.19 | 5.12
Discount rate – service costs | 5.36 | 5.38 | 5.38 | 5.37 | 5.37 | 5.31
Expected long-term return on plan assets | 8.40 | 8.40 | 8.40 | 8.40 | 8.40 | 8.40
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
Other postretirement benefit plans |  |  |  |  |  |
Discount rate – benefit obligations | 5.18 % | 5.20 % | 5.17 % | 5.17 % | 5.24 % | 5.16 %
Discount rate – interest costs | 5.08 | 5.09 | 5.07 | 5.08 | 5.12 | 5.07
Discount rate – service costs | 5.34 | 5.35 | 5.34 | 5.33 | 5.33 | 5.33
Expected long-term return on plan assets | 7.67 | 7.95 | 7.49 | 7.43 | — | 6.59
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
| 2022
Assumptions used to determine net periodic costs: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Pension plans |  |  |  |  |  |
Discount rate – benefit obligations | 3.09 % | 3.12 % | 3.07 % | 3.07 % | 3.21 % | 3.04 %
Discount rate – interest costs | 2.55 | 2.58 | 2.51 | 2.54 | 2.79 | 2.53
Discount rate – service costs | 3.34 | 3.36 | 3.37 | 3.35 | 3.36 | 3.21
Expected long-term return on plan assets | 8.25 | 8.25 | 8.25 | 8.25 | 8.25 | 8.25
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
Other postretirement benefit plans |  |  |  |  |  |
Discount rate – benefit obligations | 2.90 % | 2.95 % | 2.87 % | 2.88 % | 3.07 % | 2.82 %
Discount rate – interest costs | 2.32 | 2.38 | 2.30 | 2.27 | 2.55 | 2.17
Discount rate – service costs | 3.26 | 3.30 | 3.27 | 3.26 | 3.25 | 3.22
Expected long-term return on plan assets | 7.21 | 7.54 | 6.88 | 7.22 | — | 6.08
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
| 2021
Assumptions used to determine net periodic costs: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Pension plans |  |  |  |  |  |
Discount rate – benefit obligations | 2.81 % | 2.85 % | 2.79 % | 2.80 % | 2.99 % | 2.75 %
Discount rate – interest costs | 2.13 | 2.17 | 2.09 | 2.12 | 2.46 | 2.10
Discount rate – service costs | 3.18 | 3.23 | 3.21 | 3.20 | 3.22 | 2.97
Expected long-term return on plan assets | 8.25 | 8.25 | 8.25 | 8.25 | 8.25 | 8.25
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
Other postretirement benefit plans |  |  |  |  |  |
Discount rate – benefit obligations | 2.56 % | 2.63 % | 2.52 % | 2.53 % | 2.78 % | 2.46 %
Discount rate – interest costs | 1.84 | 1.91 | 1.82 | 1.78 | 2.12 | 1.64
Discount rate – service costs | 3.07 | 3.13 | 3.08 | 3.06 | 3.05 | 3.01
Expected long-term return on plan assets | 7.09 | 7.18 | 6.84 | 6.98 | — | 6.54
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
| 2023
Assumptions used to determine benefit obligations: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Pension plans |  |  |  |  |  |
Discount rate | 5.07 % | 5.08 % | 5.06 % | 5.06 % | 5.14 % | 5.05 %
Annual salary increase | 4.60 | 4.60 | 4.60 | 4.60 | 4.60 | 4.60
Other postretirement benefit plans |  |  |  |  |  |
Discount rate | 4.99 % | 5.01 % | 4.98 % | 4.98 % | 5.06 % | 4.98 %
Annual salary increase | 4.60 | 4.60 | 4.60 | 4.60 | 4.60 | 4.60
| 2022
Assumptions used to determine benefit obligations: | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Pension plans |  |  |  |  |  |
Discount rate | 5.25 % | 5.26 % | 5.25 % | 5.25 % | 5.31 % | 5.24 %
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
Other postretirement benefit plans |  |  |  |  |  |
Discount rate | 5.18 % | 5.20 % | 5.17 % | 5.17 % | 5.24 % | 5.16 %
Annual salary increase | 4.80 | 4.80 | 4.80 | 4.80 | 4.80 | 4.80
The Registrants estimate the expected rate of return on pension plan and other postretirement benefit plan assets using a financial model to project the expected return on each current investment portfolio. The analysis projects an expected rate of return on each of the different asset classes in order to arrive at the expected return on the entire portfolio relying on each trust's target asset allocation and reasonable capital market assumptions. The financial model is based on four key inputs: anticipated returns by asset class (based in part on historical returns), each trust's target asset allocation, an anticipated inflation rate, and the projected impact of a periodic rebalancing of each trust's portfolio. The Registrants set the expected rate of return assumption using an arithmetic mean which represents the expected simple average return to be earned by the pension plan assets over any one year. The Registrants believe the use of the arithmetic mean is more compatible with the expected rate of return's function of estimating a single year's investment return. An additional assumption used in measuring the accumulated other postretirement benefit obligations (APBO) was a weighted average medical care cost trend rate. The weighted average medical care cost trend rates used in measuring the APBO for the Registrants at December 31, 2023 were as follows:
| Initial Cost Trend Rate |  | Ultimate Cost Trend Rate |  | Year That Ultimate Rate is Reached
Pre-65 | 7.00 % |  | 4.50 % |  | 2032
Post-65 medical | 5.50 |  | 4.50 |  | 2032
Post-65 prescription | 8.50 |  | 4.50 |  | 2032
Pension Plans The total accumulated benefit obligation for the pension plans at December 31, 2023 and 2022 was as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
December 31, 2023 | $ 11,991 | $ 2,746 | $ 3,674 | $ 546 | $ 145 | $ 808
December 31, 2022 | 11,422 | 2,601 | 3,534 | 520 | 135 | 801
An actuarial loss of $0.5 billion and an actuarial gain of $3.9 billion were recorded for the annual remeasurement of the Southern Company system pension plans at December 31, 2023 and 2022, respectively, primarily due to a decrease of 18 basis points and an increase of 216 basis points, respectively, in the overall discount rate used to calculate the benefit obligation as a result of higher market interest rates. Changes in the projected benefit obligations and the fair value of plan assets during the plan years ended December 31, 2023 and 2022 were as follows:
| 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Change in benefit obligation |  |  |  |  |  |
Benefit obligation at beginning of year | $ 12,602 | $ 2,906 | $ 3,851 | $ 569 | $ 163 | $ 868
Service cost | 275 | 64 | 68 | 11 | 6 | 24
Interest cost | 626 | 145 | 191 | 28 | 8 | 42
Benefits paid | (744) | (155) | (224) | (32) | (6) | (104)
Actuarial loss | 493 | 116 | 123 | 23 | 6 | 52
Balance at end of year | 13,252 | 3,076 | 4,009 | 599 | 177 | 882
Change in plan assets |  |  |  |  |  |
Fair value of plan assets at beginning of year | 14,218 | 3,427 | 4,456 | 649 | 178 | 1,002
Actual return on plan assets | 1,092 | 260 | 331 | 50 | 12 | 79
Employer contributions | 52 | 11 | 9 | 2 | 2 | 3
Benefits paid | (744) | (154) | (225) | (32) | (7) | (104)
Fair value of plan assets at end of year | 14,618 | 3,544 | 4,571 | 669 | 185 | 980
Accrued asset | $ 1,366 | $ 468 | $ 562 | $ 70 | $ 8 | $ 98
| 2022
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Change in benefit obligation |  |  |  |  |  |
Benefit obligation at beginning of year | $ 16,382 | $ 3,806 | $ 5,012 | $ 743 | $ 222 | $ 1,134
Service cost | 412 | 99 | 103 | 17 | 9 | 34
Interest cost | 408 | 96 | 123 | 18 | 6 | 28
Benefits paid | (692) | (144) | (226) | (30) | (5) | (75)
Actuarial gain | (3,908) | (951) | (1,161) | (179) | (69) | (253)
Balance at end of year | 12,602 | 2,906 | 3,851 | 569 | 163 | 868
Change in plan assets |  |  |  |  |  |
Fair value of plan assets at beginning of year | 17,225 | 4,141 | 5,415 | 786 | 213 | 1,241
Actual loss on plan assets | (2,376) | (579) | (753) | (110) | (31) | (167)
Employer contributions | 61 | 9 | 20 | 3 | 1 | 3
Benefits paid | (692) | (144) | (226) | (30) | (5) | (75)
Fair value of plan assets at end of year | 14,218 | 3,427 | 4,456 | 649 | 178 | 1,002
Accrued asset | $ 1,616 | $ 521 | $ 605 | $ 80 | $ 15 | $ 134
The projected benefit obligations for the qualified and non-qualified pension plans at December 31, 2023 are shown in the following table. All pension plan assets are related to the qualified pension plan.
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Projected benefit obligations: |  |  |  |  |  |
Qualified pension plan | $ 12,540 | $ 2,959 | $ 3,865 | $ 569 | $ 154 | $ 822
Non-qualified pension plan | 713 | 117 | 145 | 29 | 22 | 60
Amounts recognized in the balance sheets at December 31, 2023 and 2022 related to the Registrants' pension plans consist of the following:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
December 31, 2023: |  |  |  |  |  |
Prepaid pension costs(a) | $ 2,079 | $ 585 | $ 706 | $ 99 | $ 31 | $ 158
Other regulatory assets, deferred(b) | 2,960 | 821 | 1,051 | 152 | — | 143
Other current liabilities | (64) | (11) | (13) | (2) | (2) | (3)
Employee benefit obligations(c) | (649) | (106) | (131) | (27) | (21) | (58)
Other regulatory liabilities, deferred | (47) | — | — | — | — | —
AOCI | 79 | — | — | — | 20 | (45)
December 31, 2022: |  |  |  |  |  |
Prepaid pension costs(a) | $ 2,290 | $ 629 | $ 738 | $ 108 | $ 37 | $ 183
Other regulatory assets, deferred(b) | 2,455 | 679 | 887 | 123 | — | 111
Other current liabilities | (56) | (10) | (12) | (2) | (2) | (3)
Employee benefit obligations(c) | (618) | (98) | (121) | (26) | (20) | (42)
Other regulatory liabilities, deferred | (85) | — | — | — | — | —
AOCI | 24 | — | — | — | 11 | (75)
(a)Included in prepaid pension and other postretirement benefit costs on Alabama Power's balance sheet and other deferred charges and assets on Southern Power's consolidated balance sheet. (b)Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' pension plans prior to its acquisition by Southern Company. (c)Included in other deferred credits and liabilities on Southern Power's consolidated balance sheets. Presented below are the amounts included in regulatory assets at December 31, 2023 and 2022 related to the portion of the defined benefit pension plan attributable to Southern Company, the traditional electric operating companies, and Southern Company Gas that had not yet been recognized in net periodic pension cost.
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
Balance at December 31, 2023 |  |  |  |  |
Regulatory assets: |  |  |  |  |
Prior service cost | $ 9 | $ 4 | $ 6 | $ 1 | $ (7)
Net loss | 2,904 | 817 | 1,045 | 151 | 100
Regulatory amortization | — | — | — | — | 50
Total regulatory assets(*) | $ 2,913 | $ 821 | $ 1,051 | $ 152 | $ 143
Balance at December 31, 2022 |  |  |  |  |
Regulatory assets: |  |  |  |  |
Prior service cost | $ 10 | $ 4 | $ 7 | $ 1 | $ (9)
Net loss | 2,361 | 675 | 880 | 122 | 66
Regulatory amortization | — | — | — | — | 54
Total regulatory assets(*) | $ 2,371 | $ 679 | $ 887 | $ 123 | $ 111
*Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' pension plans prior to its acquisition by Southern Company. The changes in the balance of regulatory assets related to the portion of the defined benefit pension plan attributable to Southern Company, the traditional electric operating companies, and Southern Company Gas for the years ended December 31, 2023 and 2022 are presented in the following table:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
Regulatory assets (liabilities):(*) |  |  |  |  |
Balance at December 31, 2021 | $ 2,801 | $ 809 | $ 971 | $ 146 | $ 91
Net (gain) loss | (183) | (67) | (9) | (12) | 27
Reclassification adjustments: |  |  |  |  |
Amortization of prior service costs | (1) | (1) | (1) | — | 2
Amortization of net gain (loss) | (246) | (62) | (74) | (11) | 1
Amortization of regulatory assets(*) | — | — | — | — | (10)
Total reclassification adjustments | (247) | (63) | (75) | (11) | (7)
Total change | (430) | (130) | (84) | (23) | 20
Balance at December 31, 2022 | $ 2,371 | $ 679 | $ 887 | $ 123 | $ 111
Net loss | 576 | 153 | 178 | 31 | 34
Reclassification adjustments: |  |  |  |  |
Amortization of prior service costs | (1) | (1) | (1) | — | 2
Amortization of net loss | (33) | (10) | (13) | (2) | —
Amortization of regulatory assets(*) | — | — | — | — | (4)
Total reclassification adjustments | (34) | (11) | (14) | (2) | (2)
Total change | 542 | 142 | 164 | 29 | 32
Balance at December 31, 2023 | $ 2,913 | $ 821 | $ 1,051 | $ 152 | $ 143
*Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' pension plans prior to its acquisition by Southern Company. Presented below are the amounts included in AOCI at December 31, 2023 and 2022 related to the portion of the defined benefit pension plan attributable to Southern Company, Southern Power, and Southern Company Gas that had not yet been recognized in net periodic pension cost.
| Southern Company | Southern Power | Southern Company Gas
| (in millions)
Balance at December 31, 2023 |  |  |
AOCI: |  |  |
Prior service cost | $ (1) | $ — | $ (2)
Net (gain) loss | 80 | 20 | (43)
Total AOCI | $ 79 | $ 20 | $ (45)
Balance at December 31, 2022 |  |  |
AOCI: |  |  |
Prior service cost | $ (2) | $ — | $ (3)
Net (gain) loss | 26 | 11 | (72)
Total AOCI | $ 24 | $ 11 | $ (75)
The components of OCI related to the portion of the defined benefit pension plan attributable to Southern Company, Southern Power, and Southern Company Gas for the years ended December 31, 2023 and 2022 are presented in the following table:
| Southern Company | Southern Power | Southern Company Gas
| (in millions)
AOCI: |  |  |
Balance at December 31, 2021 | $ 100 | $ 35 | $ (45)
Net gain | (82) | (22) | (30)
Reclassification adjustments: |  |  |
Amortization of net gain (loss) | 6 | (2) | —
Total change | (76) | (24) | (30)
Balance at December 31, 2022 | $ 24 | $ 11 | $ (75)
Net loss | 62 | 9 | 29
Reclassification adjustments: |  |  |
Amortization of prior service costs | 1 | — | 1
Amortization of net loss | (8) | — | —
Total reclassification adjustments | (7) | — | 1
Total change | 55 | 9 | 30
Balance at December 31, 2023 | $ 79 | $ 20 | $ (45)
Components of net periodic pension cost for the Registrants were as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |  |
Service cost | $ 275 | $ 64 | $ 68 | $ 11 | $ 6 | $ 24
Interest cost | 626 | 145 | 191 | 28 | 8 | 42
Expected return on plan assets | (1,229) | (297) | (385) | (56) | (15) | (85)
Recognized net (gain) loss | 32 | 9 | 13 | 2 | — | (5)
Net amortization | — | 1 | 1 | — | — | 15
Prior service cost | — | — | — | — | — | (3)
Net periodic pension cost (income) | $ (296) | $ (78) | $ (112) | $ (15) | $ (1) | $ (12)
2022 |  |  |  |  |  |
Service cost | $ 412 | $ 99 | $ 103 | $ 17 | $ 9 | $ 34
Interest cost | 408 | 96 | 123 | 18 | 6 | 28
Expected return on plan assets | (1,265) | (306) | (399) | (57) | (15) | (91)
Recognized net loss | 240 | 62 | 75 | 11 | 2 | 8
Net amortization | — | 1 | 1 | — | — | 15
Prior service cost | — | — | — | — | — | (3)
Net periodic pension cost (income) | $ (205) | $ (48) | $ (97) | $ (11) | $ 2 | $ (9)
2021 |  |  |  |  |  |
Service cost | $ 434 | $ 102 | $ 112 | $ 18 | $ 10 | $ 37
Interest cost | 346 | 82 | 104 | 16 | 5 | 24
Expected return on plan assets | (1,191) | (287) | (375) | (55) | (14) | (86)
Recognized net loss | 314 | 82 | 100 | 15 | 3 | 13
Net amortization | 1 | 1 | 1 | — | — | 15
Prior service cost | — | — | — | — | — | (3)
Net periodic pension cost (income) | $ (96) | $ (20) | $ (58) | $ (6) | $ 4 | $ —
The service cost component of net periodic pension cost is included in operations and maintenance expenses and all other components of net periodic pension cost are included in other income (expense), net in the Registrants' statements of income. Net periodic pension cost is the sum of service cost, interest cost, and other costs netted against the expected return on plan assets. The expected return on plan assets is determined by multiplying the expected rate of return on plan assets and the market-related value of plan assets. In determining the market-related value of plan assets, the Registrants have elected to amortize changes in the market value of return-seeking plan assets over five years and to recognize the changes in the market value of liability-hedging plan assets immediately. Given the significant concentration in return-seeking plan assets, the accounting value of plan assets that is used to calculate the expected return on plan assets differs from the current fair value of the plan assets. Future benefit payments reflect expected future service and are estimated based on assumptions used to measure the projected benefit obligation for the pension plans. At December 31, 2023, estimated benefit payments were as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Benefit Payments: |  |  |  |  |  |
2024 | $ 748 | $ 164 | $ 241 | $ 33 | $ 7 | $ 57
2025 | 776 | 171 | 248 | 34 | 7 | 59
2026 | 801 | 177 | 254 | 36 | 8 | 60
2027 | 822 | 182 | 257 | 37 | 8 | 62
2028 | 840 | 187 | 260 | 38 | 7 | 64
2029 to 2033 | 4,417 | 988 | 1,337 | 201 | 47 | 336
Other Postretirement Benefits Changes in the APBO and the fair value of the Registrants' plan assets during the plan years ended December 31, 2023 and 2022 were as follows:
| 2023
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Change in benefit obligation |  |  |  |  |  |
Benefit obligation at beginning of year | $ 1,441 | $ 344 | $ 514 | $ 59 | $ 9 | $ 179
Service cost | 15 | 4 | 4 | 1 | — | 1
Interest cost | 70 | 17 | 25 | 3 | — | 9
Benefits paid | (107) | (24) | (36) | (4) | (1) | (18)
Actuarial (gain) loss | (33) | (12) | (18) | (2) | 1 | 1
Balance at end of year | 1,386 | 329 | 489 | 57 | 9 | 172
Change in plan assets |  |  |  |  |  |
Fair value of plan assets at beginning of year | 998 | 372 | 368 | 24 | — | 113
Actual return on plan assets | 131 | 52 | 51 | 2 | — | 19
Employer contributions | 73 | 3 | 27 | 3 | 1 | 14
Benefits paid | (107) | (24) | (36) | (4) | (1) | (18)
Fair value of plan assets at end of year | 1,095 | 403 | 410 | 25 | — | 128
Accrued asset (liability) | $ (291) | $ 74 | $ (79) | $ (32) | $ (9) | $ (44)
| 2022
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Change in benefit obligation |  |  |  |  |  |
Benefit obligation at beginning of year | $ 1,849 | $ 440 | $ 656 | $ 76 | $ 11 | $ 237
Service cost | 23 | 6 | 6 | 1 | — | 1
Interest cost | 42 | 10 | 15 | 2 | — | 5
Benefits paid | (109) | (23) | (38) | (4) | (1) | (18)
Actuarial gain | (365) | (89) | (125) | (16) | (1) | (46)
Retiree drug subsidy | 1 | — | — | — | — | —
Balance at end of year | 1,441 | 344 | 514 | 59 | 9 | 179
Change in plan assets |  |  |  |  |  |
Fair value of plan assets at beginning of year | 1,251 | 489 | 450 | 29 | — | 143
Actual loss on plan assets | (218) | (98) | (71) | (4) | — | (25)
Employer contributions | 73 | 4 | 27 | 3 | 1 | 13
Benefits paid | (108) | (23) | (38) | (4) | (1) | (18)
Fair value of plan assets at end of year | 998 | 372 | 368 | 24 | — | 113
Accrued asset (liability) | $ (443) | $ 28 | $ (146) | $ (35) | $ (9) | $ (66)
Amounts recognized in the balance sheets at December 31, 2023 and 2022 related to the Registrants' other postretirement benefit plans consist of the following:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
December 31, 2023: |  |  |  |  |  |
Prepaid other postretirement benefit costs(a) | $ — | $ 74 | $ — | $ — | $ — | $ —
Other regulatory assets, deferred(b) | 23 | — | 11 | — | — | —
Other current liabilities | (6) | — | — | — | (1) | —
Employee benefit obligations(c) | (285) | — | (79) | (32) | (8) | (44)
Other regulatory liabilities, deferred | (231) | (48) | (85) | (10) | — | (68)
AOCI | (9) | — | — | — | 1 | (10)
December 31, 2022: |  |  |  |  |  |
Prepaid other postretirement benefit costs(a) | $ — | $ 28 | $ — | $ — | $ — | $ —
Other regulatory assets, deferred(b) | 34 | — | 19 | — | — | —
Other current liabilities | (6) | — | — | — | (1) | —
Employee benefit obligations(c) | (437) | — | (146) | (35) | (8) | (66)
Other regulatory liabilities, deferred | (170) | (21) | (58) | (9) | — | (58)
AOCI | (4) | — | — | — | — | (2)
(a)Included in prepaid pension and other postretirement benefit costs on Alabama Power's balance sheet. (b)Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' other postretirement benefit plans prior to its acquisition by Southern Company. (c)Included in other deferred credits and liabilities on Southern Power's consolidated balance sheets. Presented below are the amounts included in net regulatory assets (liabilities) at December 31, 2023 and 2022 related to the other postretirement benefit plans of Southern Company, the traditional electric operating companies, and Southern Company Gas that had not yet been recognized in net periodic other postretirement benefit cost.
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
Balance at December 31, 2023: |  |  |  |  |
Regulatory assets (liabilities): |  |  |  |  |
Prior service cost | $ 13 | $ 4 | $ 5 | $ 1 | $ —
Net gain | (216) | (52) | (79) | (11) | (64)
Regulatory amortization | — | — | — | — | (4)
Total regulatory assets (liabilities)(*) | $ (203) | $ (48) | $ (74) | $ (10) | $ (68)
Balance at December 31, 2022: |  |  |  |  |
Regulatory assets (liabilities): |  |  |  |  |
Prior service cost | $ 14 | $ 4 | $ 6 | $ 1 | $ 1
Net gain | (150) | (25) | (45) | (10) | (64)
Regulatory amortization | — | — | — | — | 5
Total regulatory assets (liabilities)(*) | $ (136) | $ (21) | $ (39) | $ (9) | $ (58)
*Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' other postretirement benefit plans prior to its acquisition by Southern Company. The changes in the balance of net regulatory assets (liabilities) related to the other postretirement benefit plans for the plan years ended December 31, 2023 and 2022 are presented in the following table:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
Net regulatory assets (liabilities):(*) |  |  |  |  |
Balance at December 31, 2021 | $ (74) | $ (62) | $ (10) | $ 1 | $ (34)
Net (gain) loss | (64) | 41 | (27) | (10) | (13)
Reclassification adjustments: |  |  |  |  |
Amortization of prior service costs | 1 | — | — | — | —
Amortization of net gain (loss) | 1 | — | (2) | — | —
Amortization of regulatory assets(*) | — | — | — | — | (11)
Total reclassification adjustments | 2 | — | (2) | — | (11)
Total change | (62) | 41 | (29) | (10) | (24)
Balance at December 31, 2022 | $ (136) | $ (21) | $ (39) | $ (9) | $ (58)
Net gain | (77) | (30) | (38) | (1) | —
Reclassification adjustments: |  |  |  |  |
Amortization of prior service costs | (1) | — | (1) | — | —
Amortization of net gain | 6 | 3 | 4 | — | —
Amortization of regulatory assets(*) | — | — | — | — | (10)
Total reclassification adjustments | 5 | 3 | 3 | — | (10)
Total change | (72) | (27) | (35) | (1) | (10)
Balance at December 31, 2023 | $ (208) | $ (48) | $ (74) | $ (10) | $ (68)
*Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with unamortized amounts in Southern Company Gas' other postretirement benefit plans prior to its acquisition by Southern Company. Presented below are the amounts included in AOCI at December 31, 2023 and 2022 related to the other postretirement benefit plans of Southern Company, Southern Power, and Southern Company Gas that had not yet been recognized in net periodic other postretirement benefit cost.
| Southern Company | Southern Power | Southern Company Gas
| (in millions)
Balance at December 31, 2023 |  |  |
AOCI: |  |  |
Prior service cost | $ 1 | $ — | $ —
Net (gain) loss | (10) | 1 | (10)
Total AOCI | $ (9) | $ 1 | $ (10)
Balance at December 31, 2022 |  |  |
AOCI: |  |  |
Prior service cost | $ 1 | $ — | $ —
Net (gain) loss | (5) | — | (2)
Total AOCI | $ (4) | $ — | $ (2)
The components of OCI related to the other postretirement benefit plans for the plan years ended December 31, 2023 and 2022 are presented in the following table:
| Southern Company | Southern Power | Southern Company Gas
| (in millions)
AOCI: |  |  |
Balance at December 31, 2021 | $ — | $ 2 | $ (5)
Net gain | (3) | (2) | —
Reclassification adjustments: |  |  |
Amortization of net gain (loss) | (1) | — | 3
Total change | (4) | (2) | 3
Balance at December 31, 2022 | $ (4) | $ — | $ (2)
Net (gain) loss | (12) | 1 | —
Reclassification adjustments: |  |  |
Amortization of net gain (loss) | 7 | — | (8)
Total change | (5) | 1 | (8)
Balance at December 31, 2023 | $ (9) | $ 1 | $ (10)
Components of the other postretirement benefit plans' net periodic cost for the Registrants were as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 |  |  |  |  |  |
Service cost | $ 15 | $ 4 | $ 4 | $ 1 | $ — | $ 1
Interest cost | 70 | 17 | 25 | 3 | — | 9
Expected return on plan assets | (83) | (33) | (29) | (3) | 1 | (10)
Net amortization | (11) | (3) | (3) | — | — | 6
Net periodic postretirement benefit cost (income) | $ (9) | $ (15) | $ (3) | $ 1 | $ 1 | $ 6
2022 |  |  |  |  |  |
Service cost | $ 23 | $ 6 | $ 6 | $ 1 | $ — | $ 1
Interest cost | 42 | 10 | 15 | 2 | — | 5
Expected return on plan assets | (80) | (32) | (28) | (2) | 1 | (9)
Net amortization | (1) | — | 2 | — | — | 6
Net periodic postretirement benefit cost (income) | $ (16) | $ (16) | $ (5) | $ 1 | $ 1 | $ 3
2021 |  |  |  |  |  |
Service cost | $ 24 | $ 6 | $ 7 | $ 1 | $ — | $ 2
Interest cost | 35 | 9 | 12 | 1 | — | 4
Expected return on plan assets | (76) | (30) | (26) | (1) | 1 | (10)
Net amortization | 2 | — | 2 | — | — | 6
Net periodic postretirement benefit cost (income) | $ (15) | $ (15) | $ (5) | $ 1 | $ 1 | $ 2
The service cost component of net periodic postretirement benefit cost is included in operations and maintenance expenses and all other components of net periodic postretirement benefit cost are included in other income (expense), net in the Registrants' statements of income. The Registrants' future benefit payments, including prescription drug benefits, are provided in the table below. These amounts reflect expected future service and are estimated based on assumptions used to measure the APBO for the other postretirement benefit plans.
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
Benefit payments: |  |  |  |  |  |
2024 | $ 111 | $ 24 | $ 40 | $ 5 | $ 1 | $ 17
2025 | 109 | 24 | 39 | 5 | 1 | 17
2026 | 108 | 24 | 38 | 5 | 1 | 16
2027 | 108 | 24 | 38 | 5 | 1 | 16
2028 | 108 | 25 | 38 | 4 | 1 | 15
2029 to 2033 | 523 | 123 | 188 | 21 | 1 | 64
Benefit Plan Assets Pension plan and other postretirement benefit plan assets are managed and invested in accordance with all applicable requirements, including ERISA and the Internal Revenue Code. The Registrants' investment policies for both the pension plans and the other postretirement benefit plans cover a diversified mix of assets as described below. Derivative instruments may be used to gain efficient exposure to the various asset classes and as hedging tools. Additionally, the Registrants minimize the risk of large losses primarily through diversification but also monitor and manage other aspects of risk. The investment strategy for plan assets related to the Southern Company system's qualified pension plan is to be broadly diversified across major asset classes. The asset allocation is established after consideration of various factors that affect the assets and liabilities of the pension plan including, but not limited to, historical and expected returns and interest rates, volatility, correlations of asset classes, the current level of assets and liabilities, and the assumed growth in assets and liabilities. Because a significant portion of the liability of the pension plan is long-term in nature, the assets are invested consistent with long-term investment expectations for return and risk. To manage the actual asset class exposures relative to the target asset allocation, the Southern Company system employs a formal rebalancing program. As additional risk management, external investment managers and service providers are subject to written guidelines to ensure appropriate and prudent investment practices. Management believes the portfolio is well-diversified with no significant concentrations of risk. Investment Strategies and Benefit Plan Asset Fair Values A description of the major asset classes that the pension and other postretirement benefit plans are comprised of, along with the valuation methods used for fair value measurement, is provided below:
Description | Valuation Methodology
Domestic equity: A mix of large and small capitalization stocks with generally an equal distribution of value and growth attributes, managed both actively and through passive index approaches. International equity: A mix of large and small capitalization growth and value stocks with developed and emerging markets exposure, managed both actively and through fundamental indexing approaches. | Domestic and international equities such as common stocks, American depositary receipts, and real estate investment trusts that trade on public exchanges are classified as Level 1 investments and are valued at the closing price in the active market. Equity funds with unpublished prices that are comprised of publicly traded securities (such as commingled/pooled funds) are also valued at the closing price in the active market, but are classified as Level 2.
Fixed income: A mix of domestic and international bonds. | Investments in fixed income securities, including fixed income pooled funds, are generally classified as Level 2 investments and are valued based on prices reported in the market place. Additionally, the value of fixed income securities takes into consideration certain items such as broker quotes, spreads, yield curves, interest rates, and discount rates that apply to the term of a specific instrument.
Trust-owned life insurance (TOLI): Investments of taxable trusts aimed at minimizing the impact of taxes on the portfolio. | Investments in TOLI policies are classified as Level 2 investments and are valued based on the underlying investments held in the policy's separate accounts. The underlying assets are equity and fixed income pooled funds that are comprised of Level 1 and Level 2 securities.
Real estate: Investments in equity or debt of real properties and in publicly traded real estate securities. Special situations: Investments in opportunistic strategies with the objective of diversifying and enhancing returns and exploiting short-term inefficiencies, as well as investments in promising new strategies of a longer-term nature. Private equity: Investments in private or public securities typically through privately-negotiated and/or structured transactions, including leveraged buyouts, venture capital, and distressed debt. Private credit: Investments focused on debt instruments, of which returns are driven by income rather than capital appreciation. Infrastructure: Investments in real assets, typically with long-term, predictable, and stable cash flows and a meaningful income component. | Investments in real estate, special situations, private equity, private credit, and infrastructure are typically invested in private partnerships and/or other pooled vehicles (Funds) which are generally classified as Net Asset Value as a Practical Expedient, since the Funds and underlying assets are not publicly traded and/or often have liquidity restrictions. The managers of the Funds value the assets using various inputs and techniques depending on the nature of the underlying investments. Techniques may include purchase multiples for comparable transactions, comparable public company trading multiples, discounted cash flow analysis, prevailing market capitalization rates, recent sales of comparable investments, and independent third-party appraisals. The total market value of each of the Funds is determined by aggregating the value of the underlying assets less liabilities.
For purposes of determining the fair value of the pension plan and other postretirement benefit plan assets and the appropriate level designation, management relies on information provided by the plan's trustee. This information is reviewed and evaluated by management with changes made to the trustee information as appropriate. The fair values presented herein exclude cash, receivables related to investment income and pending investment sales, and payables related to pending investment purchases. The fair values, and actual allocations relative to the target allocations, of the Southern Company system's pension plans at December 31, 2023 and 2022 are presented below.
| Fair Value Measurements Using |  |  |
| Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | Net Asset Value as a Practical Expedient |  | Target Allocation | Actual Allocation
At December 31, 2023: | (Level 1) | (Level 2) | (Level 3) | (NAV) | Total
| (in millions) |  |
Southern Company |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 1,959 | $ 771 | $ — | $ — | $ 2,730 |  |
International equity | 1,947 | 1,052 | — | — | 2,999 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 1,973 | — | — | 1,973 |  |
Mortgage- and asset-backed securities | — | 44 | — | — | 44 |  |
Corporate bonds | — | 1,724 | — | — | 1,724 |  |
Pooled funds | — | 777 | — | — | 777 |  |
Cash equivalents and other | 371 | 58 | — | — | 429 |  |
Real estate investments | 369 | — | — | 1,684 | 2,053 | 12 | 14
Special situations | — | — | — | 245 | 245 | 3 | 2
Private equity | — | — | — | 1,761 | 1,761 | 9 | 12
Private credit | — | — | — | 25 | 25 | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 4,646 | $ 6,399 | $ — | $ 3,715 | $ 14,760 | 100 % | 100 %
Alabama Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 476 | $ 187 | $ — | $ — | $ 663 |  |
International equity | 472 | 255 | — | — | 727 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 479 | — | — | 479 |  |
Mortgage- and asset-backed securities | — | 11 | — | — | 11 |  |
Corporate bonds | — | 418 | — | — | 418 |  |
Pooled funds | — | 188 | — | — | 188 |  |
Cash equivalents and other | 90 | 14 | — | — | 104 |  |
Real estate investments | 89 | — | — | 408 | 497 | 12 | 14
Special situations | — | — | — | 59 | 59 | 3 | 2
Private equity | — | — | — | 427 | 427 | 9 | 12
Private credit | — | — | — | 6 | 6 | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 1,127 | $ 1,552 | $ — | $ 900 | $ 3,579 | 100 % | 100 %
Georgia Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 611 | $ 241 | $ — | $ — | $ 852 |  |
International equity | 609 | 329 | — | — | 938 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 617 | — | — | 617 |  |
Mortgage- and asset-backed securities | — | 14 | — | — | 14 |  |
Corporate bonds | — | 539 | — | — | 539 |  |
Pooled funds | — | 243 | — | — | 243 |  |
Cash equivalents and other | 116 | 18 | — | — | 134 |  |
Real estate investments | 115 | — | — | 527 | 642 | 12 | 14
Special situations | — | — | — | 77 | 77 | 3 | 2
Private equity | — | — | — | 551 | 551 | 9 | 12
Private credit | — | — | — | 8 | 8 | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 1,451 | $ 2,001 | $ — | $ 1,163 | $ 4,615 | 100 % | 100 %
Mississippi Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 89 | $ 35 | $ — | $ — | $ 124 |  |
International equity | 89 | 48 | — | — | 137 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 90 | — | — | 90 |  |
Mortgage- and asset-backed securities | — | 2 | — | — | 2 |  |
Corporate bonds | — | 79 | — | — | 79 |  |
Pooled funds | — | 36 | — | — | 36 |  |
Cash equivalents and other | 17 | 3 | — | — | 20 |  |
Real estate investments | 17 | — | — | 77 | 94 | 12 | 14
Special situations | — | — | — | 11 | 11 | 3 | 2
Private equity | — | — | — | 81 | 81 | 9 | 12
Private credit | — | — | — | 1 | 1 | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 212 | $ 293 | $ — | $ 170 | $ 675 | 100 % | 100 %
Southern Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 24 | $ 10 | $ — | $ — | $ 34 |  |
International equity | 25 | 13 | — | — | 38 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 25 | — | — | 25 |  |
Mortgage- and asset-backed securities | — | 1 | — | — | 1 |  |
Corporate bonds | — | 22 | — | — | 22 |  |
Pooled funds | — | 10 | — | — | 10 |  |
Cash equivalents and other | 5 | 1 | — | — | 6 |  |
Real estate investments | 5 | — | — | 21 | 26 | 12 | 14
Special situations | — | — | — | 3 | 3 | 3 | 2
Private equity | — | — | — | 22 | 22 | 9 | 12
Private credit | — | — | — | — | — | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 59 | $ 82 | $ — | $ 46 | $ 187 | 100 % | 100 %
Southern Company Gas |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 41 % | 40 %
Domestic equity | $ 130 | $ 52 | $ — | $ — | $ 182 |  |
International equity | 130 | 71 | — | — | 201 |  |
Fixed income: |  |  |  |  |  | 30 | 32
U.S. Treasury, government, and agency bonds | — | 132 | — | — | 132 |  |
Mortgage- and asset-backed securities | — | 3 | — | — | 3 |  |
Corporate bonds | — | 116 | — | — | 116 |  |
Pooled funds | — | 52 | — | — | 52 |  |
Cash equivalents and other | 25 | 4 | — | — | 29 |  |
Real estate investments | 25 | — | — | 113 | 138 | 12 | 14
Special situations | — | — | — | 16 | 16 | 3 | 2
Private equity | — | — | — | 118 | 118 | 9 | 12
Private credit | — | — | — | 2 | 2 | 3 | —
Infrastructure | — | — | — | — | — | 2 | —
Total | $ 310 | $ 430 | $ — | $ 249 | $ 989 | 100 % | 100 %
| Fair Value Measurements Using |  |  |
| Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | Net Asset Value as a Practical Expedient |  | Target Allocation | Actual Allocation
At December 31, 2022: | (Level 1) | (Level 2) | (Level 3) | (NAV) | Total
| (in millions) |  |
Southern Company |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 2,078 | $ 691 | $ — | $ — | $ 2,769 |  |
International equity | 2,166 | 1,090 | — | — | 3,256 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 1,469 | — | — | 1,469 |  |
Mortgage- and asset-backed securities | — | 29 | — | — | 29 |  |
Corporate bonds | — | 1,494 | — | — | 1,494 |  |
Pooled funds | — | 607 | — | — | 607 |  |
Cash equivalents and other | 399 | 7 | — | — | 406 |  |
Real estate investments | 376 | — | — | 1,887 | 2,263 | 13 | 15
Special situations | — | — | — | 187 | 187 | 3 | 2
Private equity | — | — | — | 1,717 | 1,717 | 9 | 12
Total | $ 5,019 | $ 5,387 | $ — | $ 3,791 | $ 14,197 | 100 % | 100 %
Liabilities: |  |  |  |  |  |  |
Derivatives | (4) | — | — | — | (4) |  |
Total | $ 5,015 | $ 5,387 | $ — | $ 3,791 | $ 14,193 | 100 % | 100 %
Alabama Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 500 | $ 167 | $ — | $ — | $ 667 |  |
International equity | 522 | 263 | — | — | 785 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 354 | — | — | 354 |  |
Mortgage- and asset-backed securities | — | 7 | — | — | 7 |  |
Corporate bonds | — | 360 | — | — | 360 |  |
Pooled funds | — | 146 | — | — | 146 |  |
Cash equivalents and other | 96 | 2 | — | — | 98 |  |
Real estate investments | 91 | — | — | 455 | 546 | 13 | 15
Special situations | — | — | — | 45 | 45 | 3 | 2
Private equity | — | — | — | 414 | 414 | 9 | 12
Total | $ 1,209 | $ 1,299 | $ — | $ 914 | $ 3,422 | 100 % | 100 %
Liabilities: |  |  |  |  |  |  |
Derivatives | (1) | — | — | — | (1) |  |
Total | $ 1,208 | $ 1,299 | $ — | $ 914 | $ 3,421 | 100 % | 100 %
Georgia Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 651 | $ 217 | $ — | $ — | $ 868 |  |
International equity | 678 | 342 | — | — | 1,020 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 460 | — | — | 460 |  |
Mortgage- and asset-backed securities | — | 9 | — | — | 9 |  |
Corporate bonds | — | 468 | — | — | 468 |  |
Pooled funds | — | 190 | — | — | 190 |  |
Cash equivalents and other | 125 | 2 | — | — | 127 |  |
Real estate investments | 118 | — | — | 591 | 709 | 13 | 15
Special situations | — | — | — | 59 | 59 | 3 | 2
Private equity | — | — | — | 538 | 538 | 9 | 12
Total | $ 1,572 | $ 1,688 | $ — | $ 1,188 | $ 4,448 | 100 % | 100 %
Liabilities: |  |  |  |  |  |  |
Derivatives | (1) | — | — | — | (1) |  |
Total | $ 1,571 | $ 1,688 | $ — | $ 1,188 | $ 4,447 | 100 % | 100 %
Mississippi Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 95 | $ 32 | $ — | $ — | $ 127 |  |
International equity | 99 | 50 | — | — | 149 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 67 | — | — | 67 |  |
Mortgage- and asset-backed securities | — | 1 | — | — | 1 |  |
Corporate bonds | — | 68 | — | — | 68 |  |
Pooled funds | — | 28 | — | — | 28 |  |
Cash equivalents and other | 18 | — | — | — | 18 |  |
Real estate investments | 17 | — | — | 86 | 103 | 13 | 15
Special situations | — | — | — | 9 | 9 | 3 | 2
Private equity | — | — | — | 78 | 78 | 9 | 12
Total | $ 229 | $ 246 | $ — | $ 173 | $ 648 | 100 % | 100 %
Southern Power |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 25 | $ 9 | $ — | $ — | $ 34 |  |
International equity | 27 | 14 | — | — | 41 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 18 | — | — | 18 |  |
Corporate bonds | — | 19 | — | — | 19 |  |
Pooled funds | — | 8 | — | — | 8 |  |
Cash equivalents and other | 5 | — | — | — | 5 |  |
Real estate investments | 5 | — | — | 24 | 29 | 13 | 15
Special situations | — | — | — | 2 | 2 | 3 | 2
Private equity | — | — | — | 21 | 21 | 9 | 12
Total | $ 62 | $ 68 | $ — | $ 47 | $ 177 | 100 % | 100 %
Southern Company Gas |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |
Equity: |  |  |  |  |  | 45 % | 43 %
Domestic equity | $ 146 | $ 49 | $ — | $ — | $ 195 |  |
International equity | 152 | 77 | — | — | 229 |  |
Fixed income: |  |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 104 | — | — | 104 |  |
Mortgage- and asset-backed securities | — | 2 | — | — | 2 |  |
Corporate bonds | — | 105 | — | — | 105 |  |
Pooled funds | — | 43 | — | — | 43 |  |
Cash equivalents and other | 28 | 1 | — | — | 29 |  |
Real estate investments | 27 | — | — | 133 | 160 | 13 | 15
Special situations | — | — | — | 13 | 13 | 3 | 2
Private equity | — | — | — | 121 | 121 | 9 | 12
Total | $ 353 | $ 381 | $ — | $ 267 | $ 1,001 | 100 % | 100 %
The fair values, and actual allocations relative to the target allocations, of the applicable Registrants' other postretirement benefit plan assets at December 31, 2023 and 2022 are presented below.
| Fair Value Measurements Using |  |  |
| Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Net Asset Value as a Practical Expedient | Total | Target Allocation | Actual Allocation
At December 31, 2023: | (Level 1) | (Level 2) | (NAV)
| (in millions) |  |
Southern Company |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 60 % | 61 %
Domestic equity | $ 85 | $ 87 | $ — | $ 172 |  |
International equity | 53 | 82 | — | 135 |  |
Fixed income: |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 57 | — | 57 |  |
Mortgage- and asset-backed securities | — | 2 | — | 2 |  |
Corporate bonds | — | 47 | — | 47 |  |
Pooled funds | — | 92 | — | 92 |  |
Cash equivalents and other | 21 | 2 | — | 23 |  |
Trust-owned life insurance | — | 456 | — | 456 |  |
Real estate investments | 11 | — | 46 | 57 | 4 | 6
Special situations | — | — | 6 | 6 | 1 | 1
Private equity | — | — | 48 | 48 | 3 | 4
Private credit | — | — | 1 | 1 | 1 | —
Infrastructure | — | — | — | — | 1 | —
Total | $ 170 | $ 825 | $ 101 | $ 1,096 | 100 % | 100 %
Alabama Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 67 % | 66 %
Domestic equity | $ 16 | $ 6 | $ — | $ 22 |  |
International equity | 16 | 9 | — | 25 |  |
Fixed income: |  |  |  |  | 23 | 23
U.S. Treasury, government, and agency bonds | — | 16 | — | 16 |  |
Corporate bonds | — | 14 | — | 14 |  |
Pooled funds | — | 8 | — | 8 |  |
Cash equivalents and other | 3 | — | — | 3 |  |
Trust-owned life insurance | — | 280 | — | 280 |  |
Real estate investments | 3 | — | 14 | 17 | 4 | 6
Special situations | — | — | 2 | 2 | 1 | 1
Private equity | — | — | 15 | 15 | 3 | 4
Private credit | — | — | — | — | 1 | —
Infrastructure | — | — | — | — | 1 | —
Total | $ 38 | $ 333 | $ 31 | $ 402 | 100 % | 100 %
Georgia Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 58 % | 57 %
Domestic equity | $ 47 | $ 6 | $ — | $ 53 |  |
International equity | 16 | 40 | — | 56 |  |
Fixed income: |  |  |  |  | 35 | 35
U.S. Treasury, government, and agency bonds | — | 16 | — | 16 |  |
Corporate bonds | — | 14 | — | 14 |  |
Pooled funds | — | 47 | — | 47 |  |
Cash equivalents and other | 13 | — | — | 13 |  |
Trust-owned life insurance | — | 176 | — | 176 |  |
Real estate investments | 4 | — | 14 | 18 | 3 | 4
Special situations | — | — | 2 | 2 | 1 | 1
Private equity | — | — | 14 | 14 | 2 | 3
Private credit | — | — | — | — | 1 | —
Infrastructure | — | — | — | — | — | —
Total | $ 80 | $ 299 | $ 30 | $ 409 | 100 % | 100 %
Mississippi Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 34 % | 33 %
Domestic equity | $ 3 | $ 1 | $ — | $ 4 |  |
International equity | 3 | 1 | — | 4 |  |
Fixed income: |  |  |  |  | 43 | 44
U.S. Treasury, government, and agency bonds | — | 7 | — | 7 |  |
Corporate bonds | — | 2 | — | 2 |  |
Pooled funds | — | 1 | — | 1 |  |
Cash equivalents and other | 1 | — | — | 1 |  |
Real estate investments | 1 | — | 2 | 3 | 10 | 11
Special situations | — | — | — | — | 2 | 2
Private equity | — | — | 2 | 2 | 7 | 10
Private credit | — | — | — | — | 3 | —
Infrastructure | — | — | — | — | 1 | —
Total | $ 8 | $ 12 | $ 4 | $ 24 | 100 % | 100 %
Southern Company Gas |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 72 % | 72 %
Domestic equity | $ 2 | $ 67 | $ — | $ 69 |  |
International equity | 2 | 22 | — | 24 |  |
Fixed income: |  |  |  |  | 26 | 26
U.S. Treasury, government, and agency bonds | — | 1 | — | 1 |  |
Corporate bonds | — | 1 | — | 1 |  |
Pooled funds | — | 29 | — | 29 |  |
Cash equivalents and other | 1 | — | — | 1 |  |
Trust-owned life insurance | — | — | — | — |  |
Real estate investments | — | — | 1 | 1 | 1 | 1
Private equity | — | — | 1 | 1 | 1 | 1
Total | $ 5 | $ 120 | $ 2 | $ 127 | 100 % | 100 %
| Fair Value Measurements Using |  |  |
| Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Net Asset Value as a Practical Expedient |  | Target Allocation | Actual Allocation
At December 31, 2022: | (Level 1) | (Level 2) | (NAV) | Total
| (in millions) |  |
Southern Company |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 61 % | 59 %
Domestic equity | $ 85 | $ 74 | $ — | $ 159 |  |
International equity | 58 | 79 | — | 137 |  |
Fixed income: |  |  |  |  | 30 | 28
U.S. Treasury, government, and agency bonds | — | 43 | — | 43 |  |
Mortgage- and asset-backed securities | — | 1 | — | 1 |  |
Corporate bonds | — | 40 | — | 40 |  |
Pooled funds | — | 79 | — | 79 |  |
Cash equivalents and other | 19 | — | — | 19 |  |
Trust-owned life insurance | — | 406 | — | 406 |  |
Real estate investments | 11 | — | 51 | 62 | 5 | 7
Special situations | — | — | 6 | 6 | 1 | 1
Private equity | — | — | 46 | 46 | 3 | 5
Total | $ 173 | $ 722 | $ 103 | $ 998 | 100 % | 100 %
Alabama Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 69 % | 65 %
Domestic equity | $ 17 | $ 6 | $ — | $ 23 |  |
International equity | 18 | 9 | — | 27 |  |
Fixed income: |  |  |  |  | 23 | 23
U.S. Treasury, government, and agency bonds | — | 12 | — | 12 |  |
Corporate bonds | — | 12 | — | 12 |  |
Pooled funds | — | 7 | — | 7 |  |
Cash equivalents and other | 3 | — | — | 3 |  |
Trust-owned life insurance | — | 252 | — | 252 |  |
Real estate investments | 3 | — | 16 | 19 | 4 | 7
Special situations | — | — | 2 | 2 | 1 | 1
Private equity | — | — | 14 | 14 | 3 | 4
Total | $ 41 | $ 298 | $ 32 | $ 371 | 100 % | 100 %
Georgia Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 58 % | 56 %
Domestic equity | $ 46 | $ 6 | $ — | $ 52 |  |
International equity | 17 | 39 | — | 56 |  |
Fixed income: |  |  |  |  | 35 | 34
U.S. Treasury, government, and agency bonds | — | 10 | — | 10 |  |
Corporate bonds | — | 12 | — | 12 |  |
Pooled funds | — | 40 | — | 40 |  |
Cash equivalents and other | 9 | — | — | 9 |  |
Trust-owned life insurance | — | 154 | — | 154 |  |
Real estate investments | 4 | — | 15 | 19 | 4 | 5
Special situations | — | — | 2 | 2 | 1 | 1
Private equity | — | — | 14 | 14 | 2 | 4
Total | $ 76 | $ 261 | $ 31 | $ 368 | 100 % | 100 %
Mississippi Power |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 37 % | 35 %
Domestic equity | $ 3 | $ 1 | $ — | $ 4 |  |
International equity | 3 | 2 | — | 5 |  |
Fixed income: |  |  |  |  | 43 | 41
U.S. Treasury, government, and agency bonds | — | 4 | — | 4 |  |
Corporate bonds | — | 2 | — | 2 |  |
Pooled funds | — | 1 | — | 1 |  |
Cash equivalents and other | 2 | — | — | 2 |  |
Real estate investments | 1 | — | 3 | 4 | 11 | 12
Special situations | — | — | — | — | 2 | 2
Private equity | — | — | 2 | 2 | 7 | 10
Total | $ 9 | $ 10 | $ 5 | $ 24 | 100 % | 100 %
Southern Company Gas |  |  |  |  |  |
Assets: |  |  |  |  |  |
Equity: |  |  |  |  | 72 % | 70 %
Domestic equity | $ 2 | $ 56 | $ — | $ 58 |  |
International equity | 2 | 20 | — | 22 |  |
Fixed income: |  |  |  |  | 26 | 27
U.S. Treasury, government, and agency bonds | — | 1 | — | 1 |  |
Corporate bonds | — | 1 | — | 1 |  |
Pooled funds | — | 27 | — | 27 |  |
Cash equivalents and other | 1 | — | — | 1 |  |
Real estate investments | — | — | 2 | 2 | 1 | 2
Private equity | — | — | 1 | 1 | 1 | 1
Total | $ 5 | $ 105 | $ 3 | $ 113 | 100 % | 100 %
Employee Savings Plan Southern Company and its subsidiaries also sponsor 401(k) defined contribution plans covering substantially all employees and provide matching contributions up to specified percentages of an employee's eligible pay. Total matching contributions made to the plans for 2023, 2022, and 2021 were as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
| (in millions)
2023 | $ 131 | $ 28 | $ 31 | $ 5 | $ 3 | $ 18
2022 | 124 | 26 | 29 | 5 | 3 | 17
2021 | 119 | 26 | 28 | 5 | 2 | 16
12. STOCK COMPENSATION Stock-based compensation primarily in the form of Southern Company performance share units (PSU) and restricted stock units (RSU) may be granted through the Equity and Incentive Compensation Plan to Southern Company system employees ranging from line management to executives. At December 31, 2023, the number of current and former employees participating in stock-based compensation programs for the Registrants was as follows:
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas
Number of employees | 1,401 | 191 | 210 | 42 | 40 | 193
The majority of PSUs and RSUs awarded contain terms where employees become immediately vested in PSUs and RSUs upon retirement. As a result, compensation expense for employees that are retirement eligible at the grant date is recognized immediately, while compensation expense for employees that become retirement eligible during the vesting period is recognized over the period from grant date to the date of retirement eligibility. In addition, the Registrants recognize forfeitures as they occur. All unvested PSUs and RSUs vest immediately upon a change in control where Southern Company is not the surviving corporation. Performance Share Units PSUs granted to employees vest at the end of a three-year performance period. Shares of Southern Company common stock are delivered to employees at the end of the performance period with the number of shares issued ranging from 0% to 200% of the target number of PSUs granted, based on achievement of the performance goals established by the Compensation Committee of the Southern Company Board of Directors. Southern Company has issued two types of PSUs, each with a unique performance goal. These types of PSUs include total shareholder return (TSR) awards based on the TSR for Southern Company common stock during the three-year performance period as compared to a group of industry peers and ROE awards based on Southern Company's equity-weighted return over the performance period. The fair value of TSR awards is determined as of the grant date using a Monte Carlo simulation model. In determining the fair value of the TSR awards issued to employees, the expected volatility is based on the historical volatility of Southern Company's stock over a period equal to the performance period. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant that covers the performance period of the awards. The following table shows the assumptions used in the pricing model and the weighted average grant-date fair value of TSR awards granted:
Year Ended December 31 | 2023 |  | 2022 |  | 2021
Expected volatility | 30.0% |  | 29.6% |  | 30.0%
Expected term (in years) | 3 |  | 3 |  | 3
Interest rate | 3.8% |  | 1.7% |  | 0.2%
Weighted average grant-date fair value | $76.83 |  | $79.69 |  | $69.06
The Registrants recognize TSR award compensation expense on a straight-line basis over the three-year performance period without remeasurement. The fair values of ROE awards are based on the closing stock price of Southern Company common stock on the date of the grant. The weighted average grant-date fair value of the ROE awards granted during 2023, 2022, and 2021 was $68.93, $66.87, and $59.49, respectively. Compensation expense for ROE awards is generally recognized ratably over the three-year performance period adjusted for expected changes in ROE performance. Total compensation cost recognized for vested ROE awards reflects final performance metrics. Southern Company had 2.4 million unvested PSUs outstanding at December 31, 2022. In February 2023, the PSUs that vested for the three-year performance period ended December 31, 2022 were converted into 1.8 million shares outstanding at a share price of $67.13. During 2023, Southern Company granted 1.3 million PSUs and 1.3 million PSUs were vested or forfeited, resulting in 2.4 million unvested PSUs outstanding at December 31, 2023. In February 2024, the PSUs that vested for the three-year performance period ended December 31, 2023 were converted into 2.3 million shares outstanding at a weighted average share price of $66.95. Total PSU compensation cost, and the related tax benefit recognized in income, for the years ended December 31, 2023, 2022, and 2021 are as follows:
| 2023 |  | 2022 |  | 2021
| (in millions)
Southern Company |  |  |  |  |
Compensation cost recognized in income | $ 107 |  | $ 101 |  | $ 112
Tax benefit of compensation cost recognized in income | 28 |  | 26 |  | 29
Southern Company Gas |  |  |  |  |
Compensation cost recognized in income | $ 14 |  | $ 12 |  | $ 17
Tax benefit of compensation cost recognized in income | 4 |  | 4 |  | 4
Total PSU compensation cost and the related tax benefit recognized in income were immaterial for all periods presented for all other Registrants. The compensation cost related to the grant of Southern Company PSUs to the employees of each Subsidiary Registrant is recognized in each Subsidiary Registrant's financial statements with a corresponding credit to equity representing a capital contribution from Southern Company. At December 31, 2023, Southern Company's total unrecognized compensation cost related to PSUs was $32 million and is expected to be recognized over a weighted-average period of approximately 19 months. The total unrecognized compensation cost related to PSUs at December 31, 2023 was immaterial for all other Registrants. Restricted Stock Units The fair value of RSUs is based on the closing stock price of Southern Company common stock on the date of the grant. The weighted average grant-date fair values of RSUs granted during 2023, 2022, and 2021 were $68.95, $67.20, and $59.56, respectively. For most RSU awards, one-third of the RSUs vest each year throughout a three-year service period and compensation cost for RSUs is generally recognized over the corresponding one-, two-, or three-year vesting period. Shares of Southern Company common stock are delivered to employees at the end of each vesting period. Southern Company had 0.9 million RSUs outstanding at December 31, 2022. During 2023, Southern Company granted 0.5 million RSUs and 0.5 million RSUs were vested or forfeited, resulting in 0.9 million unvested RSUs outstanding at December 31, 2023, including RSUs related to employee retention agreements. For the years ended December 31, 2023, 2022, and 2021, Southern Company's total compensation cost for RSUs recognized in income was $30 million, $26 million, and $32 million, respectively. The related tax benefit also recognized in income was $8 million, $7 million, and $8 million for the years ended December 31, 2023, 2022, and 2021, respectively. Total unrecognized compensation cost related to RSUs at December 31, 2023, which is being recognized over a weighted-average period of approximately 17 months, is immaterial for Southern Company. Total RSUs outstanding and total compensation cost and related tax benefit for the RSUs recognized in income for the years ended December 31, 2023, 2022, and 2021, as well as the total unrecognized compensation cost at December 31, 2023, were immaterial for all other Registrants. The compensation cost related to the grant of Southern Company RSUs to the employees of each Subsidiary Registrant is recognized in such Subsidiary Registrant's financial statements with a corresponding credit to equity representing a capital contribution from Southern Company. Stock Options In 2015, Southern Company discontinued granting stock options. As of December 31, 2017, all stock option awards were vested and compensation cost fully recognized. Stock options expire no later than 10 years after the grant date and the latest possible exercise will occur by November 2024. At December 31, 2023, the weighted average remaining contractual term for the options outstanding and exercisable was approximately 2 months. Southern Company's activity in the stock option program for 2023 is summarized below:
| Shares Subject to Option |  | Weighted Average Exercise Price
| (in millions) |  |
Outstanding at December 31, 2022 | 1.0 |  | $ 42.22
Exercised | 0.7 |  | 42.54
Outstanding and Exercisable at December 31, 2023 | 0.3 |  | $ 41.58
Southern Company's cash receipts from issuances related to stock options exercised under the share-based payment arrangements for the years ended December 31, 2023, 2022, and 2021 were $28 million, $75 million, and $66 million, respectively. At December 31, 2023, the aggregate intrinsic value for options outstanding and exercisable was immaterial for all Registrants. Total intrinsic value of options exercised, and the related tax benefit, for the years ended December 31, 2023, 2022, and 2021 are presented below for Southern Company and were immaterial for all other Registrants:
Year Ended December 31 | 2023 |  | 2022 |  | 2021
| (in millions)
Southern Company |  |  |  |  |
Intrinsic value of options exercised | $ 18 |  | $ 49 |  | $ 34
Tax benefit of options exercised | 4 |  | 12 |  | 7
13. FAIR VALUE MEASUREMENTS Fair value measurements are based on inputs of observable and unobservable market data that a market participant would use in pricing the asset or liability. The use of observable inputs is maximized where available and the use of unobservable inputs is minimized for fair value measurement and reflects a three-tier fair value hierarchy that prioritizes inputs to valuation techniques used for fair value measurement. *Level 1 consists of observable market data in an active market for identical assets or liabilities. *Level 2 consists of observable market data, other than that included in Level 1, that is either directly or indirectly observable. *Level 3 consists of unobservable market data. The input may reflect the assumptions of each Registrant of what a market participant would use in pricing an asset or liability. If there is little available market data, then each Registrant's own assumptions are the best available information. In the case of multiple inputs being used in a fair value measurement, the lowest level input that is significant to the fair value measurement represents the level in the fair value hierarchy in which the fair value measurement is reported. Net asset value as a practical expedient is the classification used for assets that do not have readily determined fair values. Fund managers value the assets using various inputs and techniques depending on the nature of the underlying investments. At December 31, 2023, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:
| Fair Value Measurements Using |  |
| Quoted Prices in Active Markets for Identical Assets |  | Significant Other Observable Inputs |  | Significant Unobservable Inputs |  | Net Asset Value as a Practical Expedient |  |
At December 31, 2023: | (Level 1) |  | (Level 2) |  | (Level 3) |  | (NAV) |  | Total
| (in millions)
Southern Company |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 6 |  | $ 49 |  | $ — |  | $ — |  | $ 55
Investments in trusts:(b) |  |  |  |  |  |  |  |  |
Domestic equity | 764 |  | 216 |  | — |  | — |  | 980
Foreign equity | 145 |  | 171 |  | — |  | — |  | 316
U.S. Treasury and government agency securities | — |  | 369 |  | — |  | — |  | 369
Municipal bonds | — |  | 48 |  | — |  | — |  | 48
Pooled funds – fixed income | — |  | 6 |  | — |  | — |  | 6
Corporate bonds | — |  | 389 |  | — |  | — |  | 389
Mortgage and asset backed securities | — |  | 89 |  | — |  | — |  | 89
Private equity | — |  | — |  | — |  | 169 |  | 169
Cash and cash equivalents | 3 |  | — |  | — |  | — |  | 3
Other | 58 |  | 3 |  | — |  | 9 |  | 70
Cash equivalents and restricted cash | 253 |  | 15 |  | — |  | — |  | 268
Other investments | 9 |  | 27 |  | 8 |  | — |  | 44
Total | $ 1,238 |  | $ 1,382 |  | $ 8 |  | $ 178 |  | $ 2,806
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 46 |  | $ 312 |  | $ — |  | $ — |  | $ 358
Interest rate derivatives | — |  | 264 |  | — |  | — |  | 264
Foreign currency derivatives | — |  | 122 |  | — |  | — |  | 122
Contingent consideration | 3 |  | — |  | 16 |  | — |  | 19
Other | — |  | 13 |  | — |  | — |  | 13
Total | $ 49 |  | $ 711 |  | $ 16 |  | $ — |  | $ 776
Alabama Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 15 |  | $ — |  | $ — |  | $ 15
Nuclear decommissioning trusts:(b) |  |  |  |  |  |  |  |  |
Domestic equity | 443 |  | 208 |  | — |  | — |  | 651
Foreign equity | 145 |  | — |  | — |  | — |  | 145
U.S. Treasury and government agency securities | — |  | 20 |  | — |  | — |  | 20
Municipal bonds | — |  | 1 |  | — |  | — |  | 1
Corporate bonds | — |  | 231 |  | — |  | — |  | 231
Mortgage and asset backed securities | — |  | 25 |  | — |  | — |  | 25
Private equity | — |  | — |  | — |  | 169 |  | 169
Other | 8 |  | — |  | — |  | 9 |  | 17
Cash equivalents and restricted cash | 119 |  | 15 |  | — |  | — |  | 134
Other investments | — |  | 27 |  | — |  | — |  | 27
Total | $ 715 |  | $ 542 |  | $ — |  | $ 178 |  | $ 1,435
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 110 |  | $ — |  | $ — |  | $ 110
Georgia Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 13 |  | $ — |  | $ — |  | $ 13
Nuclear decommissioning trusts:(b) |  |  |  |  |  |  |  |  |
Domestic equity | 321 |  | 1 |  | — |  | — |  | 322
Foreign equity | — |  | 170 |  | — |  | — |  | 170
U.S. Treasury and government agency securities | — |  | 349 |  | — |  | — |  | 349
Municipal bonds | — |  | 47 |  | — |  | — |  | 47
Corporate bonds | — |  | 158 |  | — |  | — |  | 158
Mortgage and asset backed securities | — |  | 64 |  | — |  | — |  | 64
Other | 50 |  | 3 |  | — |  | — |  | 53
Total | $ 371 |  | $ 805 |  | $ — |  | $ — |  | $ 1,176
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 124 |  | $ — |  | $ — |  | $ 124
Mississippi Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 15 |  | $ — |  | $ — |  | $ 15
Cash equivalents | 17 |  | — |  | — |  | — |  | 17
Total | $ 17 |  | $ 15 |  | $ — |  | $ — |  | $ 32
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 61 |  | $ — |  | $ — |  | $ 61
Southern Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 3 |  | $ — |  | $ — |  | $ 3
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 5 |  | $ — |  | $ — |  | $ 5
Foreign currency derivatives | — |  | 22 |  | — |  | — |  | 22
Contingent consideration | 3 |  | — |  | 16 |  | — |  | 19
Other | — |  | 13 |  | — |  | — |  | 13
Total | $ 3 |  | $ 40 |  | $ 16 |  | $ — |  | $ 59
Southern Company Gas |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 6 |  | $ 3 |  | $ — |  | $ — |  | $ 9
Non-qualified deferred compensation trusts: |  |  |  |  |  |  |  |  |
Domestic equity | — |  | 7 |  | — |  | — |  | 7
Foreign equity | — |  | 1 |  | — |  | — |  | 1
Pooled funds - fixed income | — |  | 6 |  | — |  | — |  | 6
Cash and cash equivalents | 3 |  | — |  | — |  | — |  | 3
Total | $ 9 |  | $ 17 |  | $ — |  | $ — |  | $ 26
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a)(b) | $ 46 |  | $ 12 |  | $ — |  | $ — |  | $ 58
Interest rate derivatives | — |  | 79 |  | — |  | — |  | 79
Total | $ 46 |  | $ 91 |  | $ — |  | $ — |  | $ 137
(a)Excludes cash collateral of $62 million. (b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 under "Nuclear Decommissioning" for additional information. At December 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:
| Fair Value Measurements Using |  |
| Quoted Prices in Active Markets for Identical Assets |  | Significant Other Observable Inputs |  | Significant Unobservable Inputs |  | Net Asset Value as a Practical Expedient |  |
At December 31, 2022: | (Level 1) |  | (Level 2) |  | (Level 3) |  | (NAV) |  | Total
| (in millions)
Southern Company |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 18 |  | $ 181 |  | $ — |  | $ — |  | $ 199
Interest rate derivatives | — |  | 12 |  | — |  | — |  | 12
Investments in trusts:(b)(c) |  |  |  |  |  |  |  |  |
Domestic equity | 651 |  | 178 |  | — |  | — |  | 829
Foreign equity | 125 |  | 150 |  | — |  | — |  | 275
U.S. Treasury and government agency securities | — |  | 285 |  | — |  | — |  | 285
Municipal bonds | — |  | 51 |  | — |  | — |  | 51
Pooled funds – fixed income | — |  | 7 |  | — |  | — |  | 7
Corporate bonds | — |  | 412 |  | — |  | — |  | 412
Mortgage and asset backed securities | — |  | 90 |  | — |  | — |  | 90
Private equity | — |  | — |  | — |  | 161 |  | 161
Cash and cash equivalents | 4 |  | — |  | — |  | — |  | 4
Other | 37 |  | 12 |  | — |  | — |  | 49
Cash equivalents | 1,427 |  | 20 |  | — |  | — |  | 1,447
Other investments | 9 |  | 26 |  | — |  | — |  | 35
Total | $ 2,271 |  | $ 1,424 |  | $ — |  | $ 161 |  | $ 3,856
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 32 |  | $ 178 |  | $ — |  | $ — |  | $ 210
Interest rate derivatives | — |  | 302 |  | — |  | — |  | 302
Foreign currency derivatives | — |  | 216 |  | — |  | — |  | 216
Contingent consideration | — |  | — |  | 12 |  | — |  | 12
Other | — |  | 13 |  | — |  | — |  | 13
Total | $ 32 |  | $ 709 |  | $ 12 |  | $ — |  | $ 753
Alabama Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 62 |  | $ — |  | $ — |  | $ 62
Nuclear decommissioning trusts:(b) |  |  |  |  |  |  |  |  |
Domestic equity | 396 |  | 169 |  | — |  | — |  | 565
Foreign equity | 125 |  | — |  | — |  | — |  | 125
U.S. Treasury and government agency securities | — |  | 19 |  | — |  | — |  | 19
Municipal bonds | — |  | 1 |  | — |  | — |  | 1
Corporate bonds | — |  | 225 |  | — |  | — |  | 225
Mortgage and asset backed securities | — |  | 22 |  | — |  | — |  | 22
Private equity | — |  | — |  | — |  | 161 |  | 161
Other | 7 |  | — |  | — |  | — |  | 7
Cash equivalents | 438 |  | 20 |  | — |  | — |  | 458
Other investments | — |  | 26 |  | — |  | — |  | 26
Total | $ 966 |  | $ 544 |  | $ — |  | $ 161 |  | $ 1,671
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 39 |  | $ — |  | $ — |  | $ 39
Georgia Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 42 |  | $ — |  | $ — |  | $ 42
Nuclear decommissioning trusts:(b)(c) |  |  |  |  |  |  |  |  |
Domestic equity | 255 |  | 1 |  | — |  | — |  | 256
Foreign equity | — |  | 149 |  | — |  | — |  | 149
U.S. Treasury and government agency securities | — |  | 266 |  | — |  | — |  | 266
Municipal bonds | — |  | 50 |  | — |  | — |  | 50
Corporate bonds | — |  | 187 |  | — |  | — |  | 187
Mortgage and asset backed securities | — |  | 68 |  | — |  | — |  | 68
Other | 30 |  | 12 |  | — |  | — |  | 42
Cash equivalents | 355 |  | — |  | — |  | — |  | 355
Total | $ 640 |  | $ 775 |  | $ — |  | $ — |  | $ 1,415
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 62 |  | $ — |  | $ — |  | $ 62
Mississippi Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 59 |  | $ — |  | $ — |  | $ 59
Cash equivalents | 47 |  | — |  | — |  | — |  | 47
Total | $ 47 |  | $ 59 |  | $ — |  | $ — |  | $ 106
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 32 |  | $ — |  | $ — |  | $ 32
Southern Power |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 8 |  | $ — |  | $ — |  | $ 8
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives | $ — |  | $ 12 |  | $ — |  | $ — |  | $ 12
Foreign currency derivatives | — |  | 47 |  | — |  | — |  | 47
Contingent consideration | — |  | — |  | 12 |  | — |  | 12
Other | — |  | 13 |  | — |  | — |  | 13
Total | $ — |  | $ 72 |  | $ 12 |  | $ — |  | $ 84
Southern Company Gas |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a) | $ 18 |  | $ 10 |  | $ — |  | $ — |  | $ 28
Non-qualified deferred compensation trusts: |  |  |  |  |  |  |  |  |
Domestic equity | — |  | 8 |  | — |  | — |  | 8
Foreign equity | — |  | 1 |  | — |  | — |  | 1
Pooled funds - fixed income | — |  | 7 |  | — |  | — |  | 7
Cash equivalents | 4 |  | — |  | — |  | — |  | 4
Cash equivalents | 50 |  | — |  | — |  | — |  | 50
Total | $ 72 |  | $ 26 |  | $ — |  | $ — |  | $ 98
Liabilities: |  |  |  |  |  |  |  |  |
Energy-related derivatives(a)(b) | $ 32 |  | $ 33 |  | $ — |  | $ — |  | $ 65
Interest rate derivatives | — |  | 86 |  | — |  | — |  | 86
Total | $ 32 |  | $ 119 |  | $ — |  | $ — |  | $ 151
(a)Excludes cash collateral of $41 million. (b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 under "Nuclear Decommissioning" for additional information. (c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. See Note 6 under "Nuclear Decommissioning" for additional information. Valuation Methodologies The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note 14 for additional information on how these derivatives are used. For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available. The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 under "Nuclear Decommissioning" for additional information. Southern Power has contingent payment obligations related to two of its acquisitions whereby it is primarily obligated to make generation-based payments to the seller, commencing at the commercial operation of each facility and continuing through 2026 and 2035, respectively. The obligations are primarily categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility's generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial. Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments. "Other investments" primarily includes investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds. The fair value measurements of private market investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $178 million and $161 million at December 31, 2023 and 2022, respectively. Unfunded commitments related to the private market investments totaled $87 million and $78 million at December 31, 2023 and 2022, respectively. Private market investments include high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a private credit fund. Private market funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated. At December 31, 2023 and 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:
| Southern Company(*) | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas(*)
| (in billions)
At December 31, 2023: |  |  |  |  |  |
Long-term debt, including securities due within one year: |  |  |  |  |  |
Carrying amount | $ 59.4 | $ 11.2 | $ 16.5 | $ 1.6 | $ 2.7 | $ 7.8
Fair value | 55.0 | 10.1 | 15.1 | 1.4 | 2.6 | 6.8
At December 31, 2022: |  |  |  |  |  |
Long-term debt, including securities due within one year: |  |  |  |  |  |
Carrying amount | $ 54.6 | $ 10.6 | $ 14.7 | $ 1.5 | $ 3.0 | $ 7.4
Fair value | 48.6 | 9.2 | 13.0 | 1.3 | 2.8 | 6.5
*The carrying amount of Southern Company Gas' long-term debt includes fair value adjustments from the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043. The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the current rates available to the Registrants. 14. DERIVATIVES The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note 13 for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 under "Financial Instruments" for additional information. See Note 15 under "Southern Company Gas" for additional information regarding the sale of Sequent. Energy-Related Derivatives The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations. Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in operating revenues. Energy-related derivative contracts are accounted for under one of three methods: *Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism. *Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in AOCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions. *Not Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred. Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered. At December 31, 2023, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows:
| Net Purchased mmBtu |  | Longest Hedge Date |  | Longest Non-Hedge Date
| (in millions) |  |  |  |
Southern Company(*) | 448 |  | 2030 |  | 2028
Alabama Power | 118 |  | 2026 |  | —
Georgia Power | 128 |  | 2026 |  | —
Mississippi Power | 93 |  | 2028 |  | —
Southern Power | 7 |  | 2030 |  | 2024
Southern Company Gas(*) | 102 |  | 2027 |  | 2028
*Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 112 million mmBtu and short natural gas positions of 10 million mmBtu at December 31, 2023, which is also included in Southern Company's total volume. In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 12 million mmBtu for Southern Company, which includes 3 million mmBtu for Alabama Power, 4 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 3 million mmBtu for Southern Power. For cash flow hedges of energy-related derivatives, the estimated pre-tax gains (losses) expected to be reclassified from AOCI to earnings for the year ending December 31, 2024 are $(37) million for Southern Company, $(4) million for Southern Power, and $(33) million for Southern Company Gas. Interest Rate Derivatives Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred. At December 31, 2023, the following interest rate derivatives were outstanding:
| Notional Amount | Weighted Average Interest Rate Paid | Interest Rate Received | Hedge Maturity Date | Fair Value Gain (Loss) December 31, 2023
| (in millions) |  |  |  | (in millions)
Cash Flow Hedges of Forecasted Debt |  |  |  |
Georgia Power | $ 150 | 4.01% | N/A | April 2024 | $ —
Mississippi Power | 75 | 3.84% | N/A | June 2024 | —
Mississippi Power | 75 | 4.04% | N/A | June 2024 | —
Fair Value Hedges of Existing Debt |  |  |  |
Southern Company parent | 400 | 1-month SOFR + 0.80% | 1.75% | March 2028 | (46)
Southern Company parent | 1,000 | 1-month SOFR + 2.48% | 3.70% | April 2030 | (139)
Southern Company Gas | 500 | 1-month SOFR + 0.49% | 1.75% | January 2031 | (79)
Southern Company | $ 2,200 |  |  |  | $ (264)
For cash flow hedges of interest rate derivatives, the estimated pre-tax losses expected to be reclassified from AOCI to interest expense for the year ending December 31, 2024 are $19 million for Southern Company and immaterial for the traditional electric operating companies and Southern Company Gas. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2054 for Southern Company, Georgia Power, and Mississippi Power, 2052 for Alabama Power, and 2046 for Southern Company Gas. Foreign Currency Derivatives Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI. At December 31, 2023, the following foreign currency derivatives were outstanding:
| Pay Notional | Pay Rate | Receive Notional | Receive Rate | Hedge Maturity Date | Fair Value Gain (Loss) December 31, 2023
| (in millions) |  | (in millions) |  |  | (in millions)
Cash Flow Hedges of Existing Debt |  |  |  |  |
Southern Power | $ 564 | 3.78% | € 500 | 1.85% | June 2026 | $ (22)
Fair Value Hedges of Existing Debt |  |  |  |  |
Southern Company parent | 1,476 | 3.39% | 1,250 | 1.88% | September 2027 | (100)
Southern Company | $ 2,040 |  | € 1,750 |  |  | $ (122)
For cash flow hedges of foreign currency derivatives, the estimated pre-tax losses expected to be reclassified from AOCI to earnings for the year ending December 31, 2024 are $11 million for Southern Power. Derivative Financial Statement Presentation and Amounts The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties. The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:
| 2023 | 2022
Derivative Category and Balance Sheet Location | Assets | Liabilities | Assets | Liabilities
| (in millions)
Southern Company |  |  |  |
Energy-related derivatives designated as hedging instruments for regulatory purposes |  |  |  |
Assets from risk management activities/Liabilities from risk management activities | $ 12 | $ 198 | $ 123 | $ 121
Other deferred charges and assets/Other deferred credits and liabilities | 31 | 117 | 52 | 44
Total derivatives designated as hedging instruments for regulatory purposes | 43 | 315 | 175 | 165
Derivatives designated as hedging instruments in cash flow and fair value hedges |  |  |  |
Energy-related derivatives: |  |  |  |
Assets from risk management activities/Liabilities from risk management activities | — | 29 | 3 | 27
Other deferred charges and assets/Other deferred credits and liabilities | 3 | 4 | 6 | 4
Interest rate derivatives: |  |  |  |
Assets from risk management activities/Liabilities from risk management activities | — | 74 | 12 | 62
Other deferred charges and assets/Other deferred credits and liabilities | — | 190 | — | 240
Foreign currency derivatives: |  |  |  |
Assets from risk management activities/Liabilities from risk management activities | — | 34 | — | 34
Other deferred charges and assets/Other deferred credits and liabilities | — | 88 | — | 182
Total derivatives designated as hedging instruments in cash flow and fair value hedges | 3 | 419 | 21 | 549
Energy-related derivatives not designated as hedging instruments |  |  |  |
Assets from risk management activities/Liabilities from risk management activities | 8 | 8 | 13 | 13
Other deferred charges and assets/Other deferred credits and liabilities | 1 | 2 | 2 | 1
Total derivatives not designated as hedging instruments | 9 | 10 | 15 | 14
Gross amounts recognized | 55 | 744 | 211 | 728
Gross amounts offset(a) | (23) | (85) | (70) | (111)
Net amounts recognized in the Balance Sheets(b) | $ 32 | $ 659 | $ 141 | $ 617
Alabama Power(c) |  |  |  |
Energy-related derivatives designated as hedging instruments for regulatory purposes |  |  |  |
Other current assets/Other current liabilities | $ 6 | $ 69 | $ 42 | $ 21
Other deferred charges and assets/Other deferred credits and liabilities | 9 | 41 | 20 | 18
Total derivatives designated as hedging instruments for regulatory purposes | 15 | 110 | 62 | 39
Gross amounts offset | (10) | (10) | (24) | (24)
Net amounts recognized in the Balance Sheets | $ 5 | $ 100 | $ 38 | $ 15
Georgia Power |  |  |  |
Energy-related derivatives designated as hedging instruments for regulatory purposes |  |  |  |
Other current assets/Other current liabilities | $ 2 | $ 82 | $ 36 | $ 43
Other deferred charges and assets/Other deferred credits and liabilities | 10 | 42 | 6 | 18
Total derivatives designated as hedging instruments for regulatory purposes | 12 | 124 | 42 | 61
Energy-related derivatives not designated as hedging instruments |  |  |  |
Other deferred charges and assets/Other deferred credits and liabilities | 1 | — | — | 1
Gross amounts recognized | 13 | 124 | 42 | 62
Gross amounts offset | (11) | (11) | (21) | (21)
Net amounts recognized in the Balance Sheets | $ 2 | $ 113 | $ 21 | $ 41
Mississippi Power(c) |  |  |  |
Energy-related derivatives designated as hedging instruments for regulatory purposes |  |  |  |
Other current assets/Other current liabilities | $ 3 | $ 27 | $ 33 | $ 24
Other deferred charges and assets/Other deferred credits and liabilities | 12 | 34 | 26 | 8
Total derivatives designated as hedging instruments for regulatory purposes | 15 | 61 | 59 | 32
Gross amounts offset | (14) | (14) | (17) | (17)
Net amounts recognized in the Balance Sheets | $ 1 | $ 47 | $ 42 | $ 15
Southern Power |  |  |  |
Derivatives designated as hedging instruments in cash flow and fair value hedges |  |  |  |
Energy-related derivatives: |  |  |  |
Other current assets/Other current liabilities | $ — | $ 5 | $ — | $ 12
Other deferred charges and assets/Other deferred credits and liabilities | 3 | — | 5 | —
Foreign currency derivatives: |  |  |  |
Other current assets/Other current liabilities | — | 11 | — | 11
Other deferred charges and assets/Other deferred credits and liabilities | — | 11 | — | 36
Total derivatives designated as hedging instruments in cash flow and fair value hedges | 3 | 27 | 5 | 59
Energy-related derivatives not designated as hedging instruments |  |  |  |
Other current assets/Other current liabilities | — | — | 2 | —
Other deferred charges and assets/Other deferred credits and liabilities | — | — | 1 | —
Total derivatives not designated as hedging instruments | — | — | 3 | —
Net amounts recognized in the Balance Sheets | $ 3 | $ 27 | $ 8 | $ 59
Southern Company Gas |  |  |  |
Energy-related derivatives designated as hedging instruments for regulatory purposes |  |  |  |
Other current assets/Other current liabilities | $ 1 | $ 20 | $ 12 | $ 33
Derivatives designated as hedging instruments in cash flow and fair value hedges |  |  |  |
Energy-related derivatives: |  |  |  |
Other current assets/Other current liabilities | — | 24 | 3 | 15
Other deferred charges and assets/Other deferred credits and liabilities | — | 4 | 1 | 4
Interest rate derivatives: |  |  |  |
Other current assets/Other current liabilities | — | 20 | — | 14
Other deferred charges and assets/Other deferred credits and liabilities | — | 59 | — | 72
Total derivatives designated as hedging instruments in cash flow and fair value hedges | — | 107 | 4 | 105
Energy-related derivatives not designated as hedging instruments |  |  |  |
Other current assets/Other current liabilities | 7 | 8 | 11 | 12
Other deferred charges and assets/Other deferred credits and liabilities | 1 | 2 | 1 | 1
Total derivatives not designated as hedging instruments | 8 | 10 | 12 | 13
Gross amounts recognized | 9 | 137 | 28 | 151
Gross amounts offset(a) | 12 | (50) | — | (41)
Net amounts recognized in the Balance Sheets(b) | $ 21 | $ 87 | $ 28 | $ 110
(a)Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $62 million and $41 million at December 31, 2023 and 2022, respectively. (b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for all periods presented. (c)Energy-related derivatives not designated as hedging instruments were immaterial at December 31, 2022. There were no such instruments at December 31, 2023. At December 31, 2023 and 2022, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows:
Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheets
Derivative Category and Balance Sheet Location | Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Company Gas
| (in millions)
At December 31, 2023: |  |  |  |  |
Energy-related derivatives: |  |  |  |  |
Other regulatory assets, current | $ (180) | $ (67) | $ (80) | $ (25) | $ (8)
Other regulatory assets, deferred | (87) | (32) | (33) | (22) | —
Other regulatory liabilities, current | 9 | 4 | — | 1 | 4
Other regulatory liabilities, deferred | 1 | — | 1 | — | —
Total energy-related derivative gains (losses) | $ (257) | $ (95) | $ (112) | $ (46) | $ (4)
At December 31, 2022: |  |  |  |  |
Energy-related derivatives: |  |  |  |  |
Other regulatory assets, current | $ (71) | $ (8) | $ (26) | $ (13) | $ (24)
Other regulatory assets, deferred | (23) | (7) | (14) | (2) | —
Other regulatory liabilities, current | 72 | 29 | 19 | 22 | 2
Other regulatory liabilities, deferred | 31 | 9 | 2 | 20 | —
Total energy-related derivative gains (losses) | $ 9 | $ 23 | $ (19) | $ 27 | $ (22)
For the years ended December 31, 2023, 2022, and 2021, the pre-tax effects of cash flow and fair value hedge accounting on AOCI for the applicable Registrants were as follows:
Gain (Loss) From Derivatives Recognized in OCI | 2023 | 2022 | 2021
| (in millions)
Southern Company |  |  |
Cash flow hedges: |  |  |
Energy-related derivatives | $ (81) | $ 3 | $ 34
Interest rate derivatives | (12) | 46 | 5
Foreign currency derivatives | 14 | (105) | (103)
Fair value hedges(*): |  |  |
Foreign currency derivatives | 21 | (24) | (3)
Total | $ (58) | $ (80) | $ (67)
Georgia Power |  |  |
Cash flow hedges: |  |  |
Interest rate derivatives | $ (2) | $ 31 | $ —
Southern Power |  |  |
Cash flow hedges: |  |  |
Energy-related derivatives | $ (18) | $ (15) | $ 12
Foreign currency derivatives | 14 | (105) | (103)
Total | $ (4) | $ (120) | $ (91)
Southern Company Gas |  |  |
Cash flow hedges: |  |  |
Energy-related derivatives | $ (63) | $ 18 | $ 22
*Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI. The pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on AOCI were immaterial for Alabama Power for all years presented and immaterial for Mississippi Power in 2023. The pre-tax effects of cash flow and fair value hedge accounting on income for the years ended December 31, 2023, 2022, and 2021 were as follows:
Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships | 2023 | 2022 | 2021
| (in millions)
Southern Company |  |  |
Total cost of natural gas | $ 1,644 | $ 3,004 | $ 1,619
Gain (loss) on energy-related cash flow hedges(a) | (44) | 37 | 17
Total other operations and maintenance | 6,093 | 6,573 | 5,902
Gain (loss) on energy-related cash flow hedges(a) | (2) | — | —
Total depreciation and amortization | 4,525 | 3,663 | 3,565
Gain (loss) on energy-related cash flow hedges(a) | (23) | (5) | 9
Total interest expense, net of amounts capitalized | (2,446) | (2,022) | (1,837)
Gain (loss) on interest rate cash flow hedges(a) | (35) | (25) | (27)
Gain (loss) on foreign currency cash flow hedges(a) | (11) | (19) | (24)
Gain (loss) on interest rate fair value hedges(b) | 37 | (291) | (30)
Total other income (expense), net | 553 | 500 | 449
Gain (loss) on foreign currency cash flow hedges(a)(c) | 19 | (83) | (104)
Gain (loss) on foreign currency fair value hedges | 69 | (106) | (63)
Amount excluded from effectiveness testing recognized in earnings | (21) | 24 | 3
Southern Power |  |  |
Total depreciation and amortization | $ 504 | $ 516 | $ 517
Gain (loss) on energy-related cash flow hedges(a) | (23) | (5) | 9
Total interest expense, net of amounts capitalized | (129) | (138) | (147)
Gain (loss) on foreign currency cash flow hedges(a) | (11) | (19) | (24)
Total other income (expense), net | 12 | 7 | 10
Gain (loss) on foreign currency cash flow hedges(a)(c) | 19 | (83) | (104)
Southern Company Gas |  |  |
Total cost of natural gas | $ 1,644 | $ 3,004 | $ 1,619
Gain (loss) on energy-related cash flow hedges(a) | (44) | 37 | 17
Total other operations and maintenance | 1,194 | 1,176 | 1,072
Gain (loss) on energy-related cash flow hedges(a) | (2) | — | —
Total interest expense, net of amounts capitalized | (310) | (263) | (238)
Gain (loss) on interest rate cash flow hedges(a) | (19) | (4) | —
Gain (loss) on interest rate fair value hedges(b) | 6 | (86) | —
(a)Reclassified from AOCI into earnings. (b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income. (c)The reclassification from AOCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes. The pre-tax effects of cash flow hedge accounting on income for interest rate derivatives were immaterial for the traditional electric operating companies for all years presented. At December 31, 2023 and 2022, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges:
| Carrying Amount of the Hedged Item |  | Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item
Balance Sheet Location of Hedged Items | At December 31, 2023 | At December 31, 2022 |  | At December 31, 2023 | At December 31, 2022
| (in millions) |  | (in millions)
Southern Company |  |  |  |  |
Long-term debt | $ (3,024) | $ (2,927) |  | $ 235 | $ 282
Southern Company Gas |  |  |  |  |
Long-term debt | $ (427) | $ (415) |  | $ 70 | $ 81
The pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas for the years ended December 31, 2023, 2022, and 2021 were as follows:
|  | Gain (Loss)
Derivatives in Non-Designated Hedging Relationships | Statements of Income Location | 2023 |  | 2022 |  | 2021
|  | (in millions)
Energy-related derivatives | Natural gas revenues(*) | $ — |  | $ (11) |  | $ (117)
| Cost of natural gas | 59 |  | (65) |  | (27)
Total derivatives in non-designated hedging relationships | $ 59 |  | $ (76) |  | $ (144)
(*) Excludes the impact of weather derivatives recorded in natural gas revenues of $15 million and $(7) million for 2023 and 2022, respectively, as they are accounted for based on intrinsic value rather than fair value. There was no weather derivatives impact for 2021. The pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for all other Registrants for all years presented. Contingent Features The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. At December 31, 2023, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements. For Southern Company, the fair value of foreign currency derivative liabilities and interest rate derivative liabilities with contingent features, and the maximum potential collateral requirements arising from the credit-risk-related contingent features at a rating below BBB- and/or Baa3, was $52 million at December 31, 2023. For Southern Power, the fair value of foreign currency derivative liabilities with contingent features, and the maximum potential collateral requirements arising from the credit-risk-related contingent features at a rating below BBB- and/or Baa3, was immaterial at December 31, 2023. For the traditional electric operating companies and Southern Power, energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial a t December 31, 2023. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin requirements. At December 31, 2023, cash collateral posted in these accounts was immaterial for Alabama Power and Southern Power. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At December 31, 2023, cash collateral held on deposit in broker margin accounts was $62 million. The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk. Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary. Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables. The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance. 15. ACQUISITIONS AND DISPOSITIONS None of the dispositions discussed herein, both individually and combined, represented a strategic shift in operations for the applicable Registrants that has, or is expected to have, a major effect on its operations and financial results; therefore, none of the assets related to the sales have been classified as discontinued operations for any of the periods presented. Southern Company In October 2021, Southern Company completed the sale of a leveraged lease investment to the lessee for $45 million. No gain or loss was recognized on the sale; however, it did result in the recognition of approximately $16 million of additional tax benefits. Prior to the sale, in the second quarter 2021, a charge of $7 million ($6 million after tax) was recorded to reduce the investment to its estimated fair value, less costs to sell. In December 2021, Southern Company completed the termination of its leasehold interest in assets associated with its two international leveraged lease projects and received cash proceeds of approximately $673 million after the accelerated exercise of the lessee's purchase options. The pre-tax gain associated with the transaction was approximately $93 million ($99 million gain after tax). Alabama Power In September 2022, Alabama Power completed its acquisition of the Calhoun Generating Station, which was accounted for as an asset acquisition. The total purchase price was $179 million, of which $171 million was related to net assets recorded within property, plant, and equipment on the balance sheet and reflected in property additions within the investing section of the statement of cash flows. The remainder primarily related to fossil fuel stock and materials and supplies. See Note 2 under "Alabama Power – Rate CNP New Plant" for additional information. Southern Power Southern Power's acquisition-related costs for the projects discussed under "Asset Acquisitions" and "Construction Projects" were not material for any of the years presented. There were no asset acquisitions during 2022. Asset Acquisitions
Project Facility | Resource | Seller | Approximate Nameplate Capacity (MW) | Location | Southern Power Ownership Percentage | Expected/Actual COD | PPA Contract Period
Asset Acquisitions During 2023 |  |  |
Millers Branch(a) | Solar | EDF Renewables Development, Inc. | 200 | Haskell County, TX | 100% | Fourth quarter 2025 | 20 years
South Cheyenne | Solar | Hanwha Q Cells USA Corp. | 150 | Laramie County, WY | 100% | Second quarter 2024 | 20 years
Asset Acquisitions During 2021 |  |  |
Deuel Harvest(b) | Wind | Invenergy Renewables LLC | 300 | Deuel County, SD | 100% of Class B | February 2021 | 25 years and 15 years
(a)The project includes an option to expand capacity up to an additional 300 MWs. Subsequent to December 31, 2023, Southern Power committed to expand the construction of the facility through a second phase adding up to 205 MWs, with commercial operation expected to occur in the second quarter 2026. (b)In March 2021, Southern Power acquired a controlling interest in the project from Invenergy Renewables LLC and completed a tax equity transaction whereby it sold the Class A membership interests in the project. Southern Power consolidates the project's operating results in its financial statements and the tax equity partner and Invenergy Renewables LLC each own a noncontrolling interest. The aggregate purchase price for the two projects acquired during 2023 was $193 million, which is primarily recorded within construction work in progress on the balance sheet at December 31, 2023. Construction Projects
Project Facility | Resource | Approximate Nameplate Capacity (MW) | Location | COD | PPA Contract Period
Projects Completed During 2022
Garland Solar Storage(a) | Battery energy storage | 88 | Kern County, CA | September 2021 through February 2022(b) | 20 years
Tranquillity Solar Storage(a) | Battery energy storage | 72 | Fresno County, CA | November 2021 through March 2022(c) | 20 years
Projects Completed During 2021
Glass Sands(d) | Wind | 118 | Murray County, OK | November 2021 | 12 years
(a)In 2020, Southern Power restructured its ownership of the project, while retaining the controlling interests, by contributing the Class A membership interests to an existing partnership and selling 100% of the Class B membership interests. During 2021, Southern Power further restructured its ownership in the battery energy storage projects and completed tax equity transactions whereby it sold the Class A membership interests in the projects. Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest. See Note 9 under "Lessor" for additional information. (b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in 2022. (c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in 2022. (d)In December 2020, Southern Power purchased 100% of the membership interests of the Glass Sands facility. Development Projects Southern Power purchased wind turbine equipment in 2016 and 2017 for deployment to development and construction projects. All of this equipment has either been deployed to projects that have been completed or has been sold to third parties. Gains on wind turbine equipment contributed to various equity method investments totaled approximately $37 million in 2021. Southern Company Gas Sale of Sequent In July 2021, Southern Company Gas affiliates completed the sale of Sequent to Williams Field Services Group for a total cash purchase price of $159 million, including final working capital adjustments. The pre-tax gain associated with th e transaction was approximately $121 million ($92 million after tax). The sale resulted in $85 million of additional tax expense. Sale of Natural Gas Storage Facilities In September 2022, certain affiliates of Southern Company Gas entered into agreements to sell two natural gas storage facilities located in California and Texas for an aggregate purchase price of $186 million, plus working capital and certain other adjustments. The sale of the Texas facility was completed in November 2022 and the sale of the California facility was completed on September 22, 2023. Both sales resulted in an immaterial loss. Completion of the sale of the Texas facility was subject to release of a Southern Company Gas parent guarantee, which was executed in October 2022 and, as a result, Southern Company Gas recorded pre-tax impairment charges totaling approximately $131 million ($99 million after tax) in the fourth quarter 2022. 16. SEGMENT AND RELATED INFORMATION Southern Company Southern Company's reportable business segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Revenues from sales by Southern Power to the traditional electric operating companies were $537 million, $875 million, and $515 million in 2023, 2022, and 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for all periods presented. Revenues from sales of natural gas from Southern Company Gas (prior to its sale of Sequent) to Southern Power were $18 million in 2021. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications. All other inter-segment revenues are not material. Financial data for business segments and products and services for the years ended December 31, 2023, 2022, and 2021 was as follows:
| Electric Utilities |  |  |  |
| Traditional Electric Operating Companies | Southern Power | Eliminations | Total | Southern Company Gas | All Other | Eliminations | Consolidated
| (in millions)
2023 |  |  |  |  |  |  |  |
Operating revenues | $ 18,358 | $ 2,189 | $ (549) | $ 19,998 | $ 4,702 | $ 718 | $ (165) | $ 25,253
Depreciation and amortization | 3,361 | 504 | — | 3,865 | 582 | 78 | — | 4,525
Interest income | 69 | 7 | — | 76 | 9 | 26 | (26) | 85
Earnings from equity method investments | (1) | — | — | (1) | 140 | 5 | — | 144
Interest expense | 1,145 | 129 | — | 1,274 | 310 | 879 | (17) | 2,446
Income taxes (benefit) | 571 | 12 | — | 583 | 211 | (298) | — | 496
Segment net income (loss)(a)(b)(c)(d) | 3,637 | 357 | — | 3,994 | 615 | (635) | 2 | 3,976
Goodwill | — | 2 | — | 2 | 5,015 | 144 | — | 5,161
Total assets | 100,429 | 12,761 | (545) | 112,645 | 25,083 | 2,446 | (843) | 139,331
2022 |  |  |  |  |  |  |  |
Operating revenues | $ 20,408 | $ 3,369 | $ (904) | $ 22,873 | $ 5,962 | $ 593 | $ (149) | $ 29,279
Depreciation and amortization | 2,513 | 516 | — | 3,029 | 559 | 75 | — | 3,663
Interest income | 44 | 3 | — | 47 | 3 | 16 | (7) | 59
Earnings from equity method investments | — | — | — | — | 148 | 3 | — | 151
Interest expense | 929 | 138 | — | 1,067 | 263 | 694 | (2) | 2,022
Income taxes (benefit) | 828 | 20 | — | 848 | 180 | (233) | — | 795
Segment net income (loss)(a)(b)(e)(f) | 3,318 | 354 | — | 3,672 | 572 | (711) | (9) | 3,524
Goodwill | — | 2 | — | 2 | 5,015 | 144 | — | 5,161
Total assets | 95,861 | 13,081 | (659) | 108,283 | 24,621 | 2,665 | (678) | 134,891
2021 |  |  |  |  |  |  |  |
Operating revenues | $ 16,614 | $ 2,216 | $ (530) | $ 18,300 | $ 4,380 | $ 582 | $ (149) | $ 23,113
Depreciation and amortization | 2,436 | 517 | — | 2,953 | 536 | 76 | — | 3,565
Interest income | 20 | 1 | — | 21 | — | 4 | (3) | 22
Earnings from equity method investments | 1 | — | — | 1 | 50 | 24 | 1 | 76
Interest expense | 821 | 147 | — | 968 | 238 | 631 | — | 1,837
Income taxes (benefit) | 232 | (13) | — | 219 | 275 | (227) | — | 267
Segment net income (loss)(a)(b)(g)(h)(i) | 1,981 | 266 | — | 2,247 | 539 | (384) | (9) | 2,393
Goodwill | — | 2 | — | 2 | 5,015 | 263 | — | 5,280
Total assets | 89,051 | 13,390 | (667) | 101,774 | 23,560 | 2,975 | (775) | 127,534
(a)Attributable to Southern Company. (b)For the traditional electric operating companies, includes pre-tax charges (credits) to income at Georgia Power for the estimated probable loss associated with the construction of Plant Vogtle Units 3 and 4 of $(68) million ($(50) million after tax) in 2023, $183 million ($137 million after tax) in 2022, and $1.7 billion ($1.3 billion after tax) in 2021. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. (c)For Southern Power, includes an $18 million pre-tax loss recovery ($9 million after tax and partnership allocations) related to an arbitration award and a $16 million pre-tax gain ($12 million after tax) on the sale of spare parts. See Note 3 under "General Litigation Matters – Southern Power" for additional information. (d)For Southern Company Gas, includes pre-tax charges totaling approximately $96 million ($72 million after tax) associated with the disallowance of certain capital investments at Nicor Gas. See Note 2 under "Southern Company Gas" for additional information. (e)For Southern Company Gas, includes pre-tax impairment charges totaling approximately $131 million ($99 million after tax) related to the sale of natural gas storage facilities. See Note 15 under "Southern Company Gas" for additional information. (f)For the "All Other" column, includes a $119 million goodwill impairment loss (pre-tax and after tax) at PowerSecure. See Note 1 under "Goodwill and Other Intangible Assets" for additional information. (g)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Notes 7 and 15 under "Southern Power" for additional information. (h)For Southern Company Gas, includes a pre-tax gain of $121 million ($92 million after tax) related to its sale of Sequent, as well as the resulting $85 million of additional tax expense due to changes in state apportionment rates, and pre-tax impairment charges totaling $84 million ($67 million after tax) related to its equity method investment in the PennEast Pipeline project. See Notes 7 and 15 under "Southern Company Gas" for additional information. (i)For the "All Other" column, includes a pre-tax gain of $93 million ($99 million gain after tax) associated with the termination of two leveraged leases projects. See Note 15 under "Southern Company" for additional information. Products and Services
Electric Utilities' Revenues
Year | Retail |  | Wholesale |  | Other |  | Total
| (in millions)
2023 | $ 16,343 |  | $ 2,467 |  | $ 1,188 |  | $ 19,998
2022 | 18,197 |  | 3,641 |  | 1,035 |  | 22,873
2021 | 14,852 |  | 2,455 |  | 993 |  | 18,300
Southern Company Gas' Revenues
Year | Gas Distribution Operations |  | Gas Marketing Services |  | All Other |  | Total
| (in millions)
2023 | $ 4,090 |  | $ 548 |  | $ 64 |  | $ 4,702
2022 | 5,240 |  | 638 |  | 84 |  | 5,962
2021 | 3,656 |  | 475 |  | 249 |  | 4,380
Southern Company Gas Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 under "Southern Company Gas" for additional information on the disposition activities described herein. Gas distribution operations is the largest component of Southern Company Gas' business and includes natural gas local distribution utilities that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in four states. Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a 50% interest in SNG and a 50% joint ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the customers of Southern Company Gas. See Notes 5 and 7 for additional information. Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities. Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar. The all other column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage and fuels operations. The all other column included a natural gas storage facility in Texas through its sale in November 2022 and a natural gas storage facility in California through its sale in September 2023. Financial data for business segments for the years ended December 31, 2023, 2022, and 2021 was as follows:
| Gas Distribution Operations | Gas Pipeline Investments | Wholesale Gas Services(a) | Gas Marketing Services | Total | All Other | Eliminations | Consolidated
| (in millions)
2023 |  |  |  |  |
Operating revenues | $ 4,105 | $ 32 | $ — | $ 548 | $ 4,685 | $ 36 | $ (19) | $ 4,702
Depreciation and amortization | 561 | 5 | — | 15 | 581 | 1 | — | 582
Operating income (loss) | 804 | 22 | — | 130 | 956 | (4) | (13) | 939
Earnings from equity method investments | — | 140 | — | — | 140 | — | — | 140
Interest expense | 275 | 32 |  | 3 | 310 | — | — | 310
Income taxes | 126 | 32 | — | 37 | 195 | 16 | — | 211
Segment net income (loss)(b) | 441 | 98 | — | 91 | 630 | (15) | — | 615
Total assets | 22,906 | 1,534 | — | 1,615 | 26,055 | 9,675 | (10,647) | 25,083
2022 |  |  |  |  |
Operating revenues | $ 5,267 | $ 32 | $ — | $ 638 | $ 5,937 | $ 55 | $ (30) | $ 5,962
Depreciation and amortization | 516 | 5 | — | 16 | 537 | 22 | — | 559
Operating income (loss) | 803 | 21 | — | 133 | 957 | (135) | (8) | 814
Earnings from equity method investments | — | 148 | — | — | 148 | — | — | 148
Interest expense | 229 | 27 | — | 3 | 259 | 4 | — | 263
Income taxes (benefit) | 145 | 35 | — | 37 | 217 | (37) | — | 180
Segment net income (loss)(c) | 470 | 107 | — | 94 | 671 | (99) | — | 572
Total assets | 22,040 | 1,577 | — | 1,616 | 25,233 | 8,943 | (9,555) | 24,621
2021 |  |  |  |  |
Operating revenues | $ 3,679 | $ 32 | $ 188 | $ 475 | $ 4,374 | $ 38 | $ (32) | $ 4,380
Depreciation and amortization | 482 | 5 | — | 18 | 505 | 31 | — | 536
Operating income (loss) | 708 | 21 | 241 | 125 | 1,095 | (40) | — | 1,055
Earnings from equity method investments | — | 50 | — | — | 50 | — | — | 50
Interest expense | 207 | 25 | 2 | 3 | 237 | 1 | — | 238
Income taxes | 120 | 27 | 32 | 34 | 213 | 62 | — | 275
Segment net income (loss)(d)(e)(f) | 412 | 19 | 107 | 88 | 626 | (87) | — | 539
Total assets | 20,917 | 1,467 | 31 | 1,556 | 23,971 | 12,114 | (12,525) | 23,560
(a)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment in 2023 or 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.
| Third Party Gross Revenues | Intercompany Revenues | Total Gross Revenues | Less Gross Gas Costs | Operating Revenues
| (in millions)
2021 | $ 3,881 | $ 90 | $ 3,971 | $ 3,783 | $ 188
(b)For gas distribution operations, includes pre-tax charges totaling approximately $96 million ($72 million after tax) associated with the disallowance of certain capital investments at Nicor Gas. See Note 2 under "Southern Company Gas" for additional information. (c)For the "All Other" column, includes pre-tax impairment charges totaling approximately $131 million ($99 million after tax) related to the sale of natural gas storage facilities. See Note 15 under "Southern Company Gas" for additional information. (d)For gas pipeline investments, includes pre-tax impairment charges totaling $84 million ($67 million after tax) related to the equity method investment in the PennEast Pipeline project. See Note 7 under "Southern Company Gas" for additional information. (e)For wholesale gas services, includes a pre-tax gain of $121 million ($92 million after tax) related to the sale of Sequent. (f)For the "All Other" column, includes $85 million of additional tax expense as a result of the sale of Sequent.
3. CONTINGENCIES, COMMITMENTS, AND GUARANTEES General Litigation Matters The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements. The Registrants intend to dispute the allegations raised in and vigorously defend against the pending legal challenges discussed below; however, the ultimate outcome of these matters cannot be determined at this time. Southern Company and Mississippi Power In 2010, the DOE, through a cooperative agreement with SCS, agreed to fund $270 million of the Kemper County energy facility through the grants awarded to the project by the DOE under the Clean Coal Power Initiative Round 2. In 2016, additional DOE grants in the amount of $137 million were awarded to the Kemper County energy facility. In 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the $387 million of total grants received. In 2020, Mississippi Power and Southern Company executed an agreement with the DOE completing Mississippi Power's request, which enabled Mississippi Power to proceed with full dismantlement of the abandoned gasifier-related assets and site restoration activities. In connection with the DOE closeout discussions, in 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of a civil investigation related to the DOE grants. On August 4, 2023, the U.S. District Court for the Northern District of Georgia unsealed a civil action in which defendants Southern Company, SCS, and Mississippi Power are alleged to have violated certain provisions of the False Claims Act by fraudulently inducing the DOE to disburse funds pursuant to the grants. The federal government declined to intervene in the action. On October 30, 2023, the plaintiff, a former SCS employee, filed an amended complaint, again alleging certain violations of the False Claims Act. The plaintiff seeks to recover all damages incurred personally and on behalf of the government caused by the defendants' alleged violations, as well as treble damages and attorneys' fees, among other relief. The ultimate outcome of this matter cannot be determined at this time; however, an adverse outcome could have a material impact on Southern Company's and Mississippi Power's financial statements. Alabama Power In September 2022, Mobile Baykeeper filed a citizen suit in the U.S. District Court for the Southern District of Alabama alleging that Alabama Power's plan to close the Plant Barry ash pond utilizing a closure-in-place methodology violates the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Among other relief requested, Mobile Baykeeper sought a declaratory judgment that the RCRA and regulations governing CCR were being violated, preliminary and injunctive relief to prevent implementation of Alabama Power's closure plan and the development of a closure plan that satisfies regulations governing CCR requirements. In December 2022, Alabama Power filed a motion to dismiss the case. On January 4, 2024, the lawsuit was dismissed without prejudice by the U.S. District Court judge. On February 1, 2024, the plaintiff filed a motion to reconsider. On January 31, 2023, the EPA issued a Notice of Potential Violations associated with Alabama Power's plan to close the Plant Barry ash pond. Alabama Power has affirmed to the EPA its position that it is in compliance with CCR requirements. The ultimate outcome of this matter cannot be determined at this time but could have a material impact on Alabama Power's ARO estimates and cash flows. See Note 6 for a discussion of Alabama Power's ARO liabilities. Georgia Power In July 2020, a group of individual plaintiffs filed a complaint, which was amended in December 2022, in the Superior Court of Fulton County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer has impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. In December 2022, the Superior Court of Fulton County, Georgia granted Georgia Power's motion to transfer the case to the Superior Court of Monroe County, Georgia. On May 9, 2023, the Superior Court of Monroe County, Georgia denied Georgia Power's motion to dismiss the case for lack of subject matter jurisdiction. On July 27, 2023, the Superior Court of Monroe County, Georgia denied the remaining motions to dismiss certain claims and plaintiffs that Georgia Power filed at the outset of the case. In October 2021, February 2022, and January 2023, a total of eight additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs sought an unspecified amount of monetary damages including punitive damages. After Georgia Power removed these cases to the U.S. District Court for the Middle District of Georgia, the plaintiffs voluntarily dismissed their complaints without prejudice in November 2022 and January 2023. On May 12, 2023, the plaintiffs in the cases originally filed in October 2021, February 2022, and January 2023 refiled their eight complaints in the Superior Court of Monroe County, Georgia. Also on May 12, 2023, a new complaint was filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries. The plaintiff seeks an unspecified amount of monetary damages, including punitive damages. On May 18, 2023, Georgia Power removed all of these cases to the U.S. District Court for the Middle District of Georgia. The plaintiffs are requesting the court remand the cases back to the Superior Court of Monroe County, Georgia. The amount of possible loss, if any, from these matters cannot be estimated at this time. See Note 17 under "Georgia Power - General Litigation Matters" for additional information. Mississippi Power In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. In March 2022, the U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. In May 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. In June 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint with prejudice, which was granted on March 15, 2023. On March 28, 2023, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On December 14, 2023, the U.S. Court of Appeals for the Fifth Circuit affirmed the district court's order dismissing the plaintiffs' complaint against Mississippi Power. On December 28, 2023, the plaintiffs filed a petition for panel rehearing, which was denied on January 10, 2024. The plaintiffs have until April 9, 2024 to file a petition for writ of certiorari with the U.S. Supreme Court. The ultimate outcome of this matter cannot be determined at this time. Southern Power In July 2021, Southern Power and certain of its subsidiaries filed an arbitration demand with the American Arbitration Association against First Solar Electric, LLC (First Solar) for defective design of actuators on trackers and inverters installed by First Solar under the engineering, procurement, and construction agreements associated with five solar projects owned by Southern Power and partners and managed by Southern Power. In February 2023, arbitration hearings concluded. In July 2023, an interim award of approximately $36 million was entered in favor of Southern Power and was subsequently received in September 2023. The interim award included $18 million representing recovery of losses associated with replacement costs, penalty payments, and lost revenues previously incurred. This recovery is reflected in Southern Power's 2023 statement of income as an $11 million reduction to other operations and maintenance expense and a $7 million increase in other revenues, with $6 million allocated through noncontrolling interests to Southern Power's partners. The remaining $18 million in award proceeds received in excess of the losses incurred is recognized on the balance sheet at December 31, 2023 as restricted cash and a liability to fund future replacement costs. In November 2023, the final award was issued and Southern Power filed for confirmation of the final award in the Delaware Court of Chancery. In December 2023, First Solar filed a motion to dismiss the confirmation and, in February 2024, filed a petition to vacate the arbitration award in the Supreme Court of New York County, New York. The ultimate outcome of this matter cannot be determined at this time. Environmental Remediation The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities conduct studies to determine the extent of any required cleanup and have recognized the estimated costs to clean up known impacted sites in the financial statements. A liability for environmental remediation costs is recognized only when a loss is determined to be probable and reasonably estimable and is reduced as expenditures are incurred. The traditional electric operating companies and the natural gas distribution utilities in Illinois and Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental remediation costs through regulatory mechanisms. Any difference between the liabilities accrued and costs recovered through rates is deferred as a regulatory asset or liability. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable state regulatory agencies. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected. For 2023, 2022, and 2021, Georgia Power recovered approximately $5 million, $12 million, and $12 million, respectively, through the ECCR tariff for environmental remediation. Southern Company Gas is subject to environmental remediation liabilities associated with 40 former manufactured gas plant sites in four different states. Southern Company Gas' accrued environmental remediation liability at December 31, 2023 and 2022 was based on the estimated cost of environmental investigation and remediation associated with these sites. At December 31, 2023 and 2022, the environmental remediation liability and the balance of under recovered environmental remediation costs were reflected in the balance sheets of Southern Company, Georgia Power, and Southern Company Gas as shown in the table below. Alabama Power and Mississippi Power did not have environmental remediation liabilities at December 31, 2023 or 2022.
| Southern Company | Georgia Power | Southern Company Gas
| (in millions)
December 31, 2023: |  |  |
Environmental remediation liability: |  |  |
Other current liabilities | $ 44 | $ 14 | $ 30
Accrued environmental remediation | 192 | — | 192
Under recovered environmental remediation costs: |  |  |
Other regulatory assets, current | $ 45 | $ 5 | $ 40
Other regulatory assets, deferred | 210 | 15 | 195
December 31, 2022: |  |  |
Environmental remediation liability: |  |  |
Other current liabilities | $ 65 | $ 15 | $ 49
Accrued environmental remediation | 207 | — | 207
Under recovered environmental remediation costs: |  |  |
Other regulatory assets, current | $ 59 | $ 5 | $ 54
Other regulatory assets, deferred | 235 | 20 | 215
The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants. Nuclear Fuel Disposal Costs Acting through the DOE and pursuant to the Nuclear Waste Policy Act of 1982, the U.S. government entered into contracts with Alabama Power and Georgia Power that required the DOE to take title to and dispose of spent nuclear fuel generated at Plants Farley, Hatch, and Vogtle Units 1 and 2 beginning no later than January 31, 1998. The DOE has yet to commence performance of its contractual and statutory obligation to dispose of spent nuclear fuel. Consequently, Alabama Power and Georgia Power pursued and continue to pursue legal remedies against the U.S. government for its partial breach of contract. In 2014, Alabama Power and Georgia Power filed their third round of lawsuits against the U.S. government in the Court of Federal Claims, seeking damages for the costs of continuing to store spent nuclear fuel at Plants Farley, Hatch, and Vogtle Units 1 and 2 for the period from January 1, 2011 through December 31, 2013. The damage period was subsequently extended to December 31, 2014. In 2019, the Court of Federal Claims granted Alabama Power's and Georgia Power's motion for summary judgment on damages not disputed by the U.S. government, awarding those undisputed damages to Alabama Power and Georgia Power. However, those undisputed damages are not collectible until the court enters final judgment on the remaining damages. In 2017, Alabama Power and Georgia Power filed their fourth round of lawsuits against the U.S. government in the Court of Federal Claims, seeking damages for the costs of continuing to store spent nuclear fuel at Plants Farley, Hatch, and Vogtle Units 1 and 2 for the period from January 1, 2015 through December 31, 2017. In 2020, Alabama Power and Georgia Power filed amended complaints in those fourth-round lawsuits adding damages incurred from January 1, 2018 to December 31, 2019 to the claim period. The outstanding claims for the period January 1, 2011 through December 31, 2019 total $106 million and $128 million for Alabama Power and Georgia Power (based on its ownership interests), respectively. Damages will continue to accumulate until the issue is resolved, the U.S. government disposes of Alabama Power's and Georgia Power's spent nuclear fuel pursuant to its contractual obligations, or alternative storage is otherwise provided. No amounts have been recognized in the financial statements as of December 31, 2023 for any potential recoveries from the pending lawsuits. The final outcome of these matters cannot be determined at this time. However, Alabama Power and Georgia Power expect to credit any recoveries for the benefit of customers in accordance with direction from their respective PSC; therefore, no material impact on Southern Company's, Alabama Power's, or Georgia Power's net income is expected. On-site dry spent fuel storage facilities are operational at all three plants and can be expanded to accommodate spent fuel through the expected life of each plant. Nuclear Insurance Under the Price-Anderson Amendments Act (Act), Alabama Power and Georgia Power maintain agreements of indemnity with the NRC that, together with private insurance, cover third-party liability arising from any nuclear incident occurring at the companies' nuclear power plants. The Act provides funds up to $16.2 billion for public liability claims that could arise from a single nuclear incident. Each nuclear plant is insured against this liability to a maximum of $450 million by American Nuclear Insurers (ANI), with the remaining coverage provided by a mandatory program of deferred premiums that could be assessed, after a nuclear incident, against all owners of commercial nuclear reactors. A company could be assessed up to $166 million per incident for each licensed reactor it operates but not more than an aggregate of $25 million per incident to be paid in a calendar year for each reactor. Such maximum assessment, excluding any applicable state premium taxes, for Alabama Power and Georgia Power, based on its ownership and buyback interests in all licensed reactors, is $332 million and $473 million, respectively, per incident, but not more than an aggregate of $49 million and $71 million, respectively, to be paid for each incident in any one year. Both the maximum assessment per reactor and the maximum yearly assessment are adjusted for inflation at least every five years. The next scheduled adjustment is due no later than November 1, 2028. See Note 5 under "Joint Ownership Agreements" for additional information on joint ownership agreements. Alabama Power and Georgia Power are members of Nuclear Electric Insurance Limited (NEIL), a mutual insurer established to provide property damage insurance in an amount up to $1.5 billion for members' operating nuclear generating facilities. Additionally, both companies have NEIL policies that currently provide decontamination, excess property insurance, and premature decommissioning coverage up to $1.25 billion for nuclear losses and policies providing coverage up to $750 million for non-nuclear losses in excess of the $1.5 billion primary coverage. NEIL also covers the additional costs that would be incurred in obtaining replacement power during a prolonged accidental outage at a member's nuclear plant. Members can purchase this coverage, subject to a deductible waiting period of up to 26 weeks, with a maximum per occurrence per unit limit of $490 million. After the deductible period, weekly indemnity payments would be received until either the unit is operational or until the limit is exhausted. Alabama Power and Georgia Power each purchase limits based on the projected full cost of replacement power, subject to ownership limitations, and have each elected a 12-week deductible waiting period for each nuclear plant. A builders' risk property insurance policy has been purchased from NEIL for the construction of Plant Vogtle Unit 4. This policy provides the Vogtle Owners up to $2.75 billion for accidental property damage occurring during construction. Under each of the NEIL policies, members are subject to assessments each year if losses exceed the accumulated funds available to the insurer. The maximum annual assessments for Alabama Power and Georgia Power as of December 31, 2023 under the NEIL policies would be $54 million and $89 million, respectively. Claims resulting from terrorist acts and cyber events are covered under both the ANI and NEIL policies (subject to normal policy limits). The maximum aggregate that NEIL will pay for all claims resulting from terrorist acts and cyber events in any 12-month period is $3.2 billion each, plus such additional amounts NEIL can recover through reinsurance, indemnity, or other sources. For all on-site property damage insurance policies for commercial nuclear power plants, the NRC requires that the proceeds of such policies shall be dedicated first for the sole purpose of placing the reactor in a safe and stable condition after an accident. Any remaining proceeds are to be applied next toward the costs of decontamination and debris removal operations ordered by the NRC, and any further remaining proceeds are to be paid either to the applicable company or to its debt trustees as may be appropriate under the policies and applicable trust indentures. In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers, would be borne by Alabama Power or Georgia Power, as applicable, and could have a material effect on Southern Company's, Alabama Power's, and Georgia Power's financial condition and results of operations. All retrospective assessments, whether generated for liability, property, or replacement power, may be subject to applicable state premium taxes. Other Matters Traditional Electric Operating Companies In April 2019, Bellsouth Telecommunications d/b/a AT&T Alabama (AT&T) filed a complaint against Alabama Power with the FCC alleging that the pole rental rate AT&T is required to pay pursuant to the parties' joint use agreement is unjust and unreasonable under federal law. The complaint sought a new rate and approximately $87 million in refunds of alleged overpayments for the preceding six years. In August 2019, the FCC stayed the case in favor of arbitration, which AT&T has not pursued. The joint use agreement remains in effect. The ultimate outcome of this matter cannot be determined at this time, but an adverse outcome could have a material impact on the financial statements of Southern Company and Alabama Power. Georgia Power and Mississippi Power have joint use agreements with other AT&T affiliates. Mississippi Power Kemper County Energy Facility In 2021, 2022, and 2023, Mississippi Power recorded charges to income associated with abandonment and related closure costs and ongoing period costs, net of salvage proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. These charges, including related tax impacts, totaled $11 million pre-tax ($8 million after tax) in 2021, $15 million pre-tax ($12 million after tax) in 2022, and $17 million pre-tax ($12 million after tax) in 2023. The pre-tax charges are included in other operations and maintenance expenses on the statements of income. Dismantlement of the abandoned gasifier-related assets and site restoration activities are expected to be completed by 2026. Additional pre-tax period costs associated with dismantlement and site restoration activities, including related costs for compliance and safety, ARO accretion, and property taxes, net of salvage, are estimated to total approximately $15 million annually through 2025. Mississippi Power owns the lignite mine located around the Kemper County energy facility site. As a result of the abandonment of the Kemper IGCC, final mine reclamation began in 2018 and was substantially completed in 2020, with monitoring expected to continue through 2028. As the mining permit holder, Liberty Fuels Company, LLC, a wholly-owned subsidiary of The North American Coal Corporation, has a legal obligation to perform mine reclamation and Mississippi Power has a contractual obligation to fund all reclamation activities. See Note 6 for additional information. See "General Litigation Matters – Southern Company and Mississippi Power" herein for information regarding litigation associated with the Kemper County energy facility. Plant Daniel In conjunction with Southern Company's 2019 sale of Gulf Power, NextEra Energy held back $75 million of the purchase price pending Mississippi Power and NextEra Energy negotiating a mutually acceptable revised operating agreement for Plant Daniel. In July 2022, the co-owners executed a revised operating agreement and Southern Company subsequently received the remaining $75 million of the purchase price. The dispatch procedures in the revised operating agreement for the two jointly-owned coal units at Plant Daniel resulted in Mississippi Power designating one of the two units as primary and the other as secondary in lieu of each company separately owning 100% of a single generating unit. Mississippi Power did not exercise an option to purchase its co-owner's ownership interest for $1 on January 15, 2024. The revised operating agreement did not have a material impact on Mississippi Power's financial statements. See Note 2 under "M ississippi Power – Integrated Resource Plan" for additional information on Plant Daniel. Commitments To supply a portion of the fuel requirements of the Southern Company system's electric generating plants, the Southern Company system has entered into various long-term commitments not recognized on the balance sheets for the procurement and delivery of fossil fuel and, for Alabama Power and Georgia Power, nuclear fuel. The majority of the Registrants' fuel expense for the periods presented was purchased under long-term commitments. Each Registrant expects that a substantial amount of its future fuel needs will continue to be purchased under long-term commitments. Georgia Power has commitments, in the form of capacity purchases, regarding a portion of a 5% interest in the original cost of Plant Vogtle Units 1 and 2 owned by MEAG Power that are in effect until the later of the retirement of the plant or the latest stated maturity date of MEAG Power's bonds issued to finance such ownership interest. The payments for capacity are required whether or not any capacity is available. Portions of the capacity payments made to MEAG Power for its Plant Vogtle Units 1 and 2 investment relate to costs in excess of Georgia Power's allowed investment for ratemaking purposes. The present value of these portions at the time of the disallowance was written off. Generally, the cost of such capacity is included in purchased power in Southern Company's statements of income and in purchased power, non-affiliates in Georgia Power's statements of income. Georgia Power's capacity payments related to this commitment totaled $3 million, $4 million, and $6 million in 2023, 2022, and 2021, respectively. At December 31, 2023, Georgia Power's estimated long-term obligations related to this commitment totaled $39 million, consisting of $4 million annually for 2024 and 2025, $2 million annually for 2026 through 2028, and $25 million thereafter. See Note 9 for information regarding PPAs accounted for as leases. Southern Company Gas has commitments for pipeline charges, storage capacity, and gas supply, including charges recoverable through natural gas cost recovery mechanisms or, alternatively, billed to marketers selling retail natural gas. Gas supply commitments include amounts for gas commodity purchases associated with Nicor Gas and SouthStar of 38 million mmBtu at floating gas prices calculated using forward natural gas prices at December 31, 2023 and valued at $98 million. Southern Company Gas provides guarantees to certain gas suppliers for certain of its subsidiaries in support of payment obligations. Southern Company Gas' expected future contractual obligations for pipeline charges, storage capacity, and gas supply that are not recognized on the balance sheets at December 31, 2023 were as follows:
| Pipeline Charges, Storage Capacity, and Gas Supply
| (in millions)
2024 | $ 587
2025 | 432
2026 | 231
2027 | 148
2028 | 103
Thereafter | 785
Total | $ 2,286
Guarantees SCS may enter into various types of wholesale energy and natural gas contracts acting as an agent for the traditional electric operating companies and Southern Power. Under these agreements, each of the traditional electric operating companies and Southern Power may be jointly and severally liable. Accordingly, Southern Company has entered into keep-well agreements with each of the traditional electric operating companies to ensure they will not subsidize or be responsible for any costs, losses, liabilities, or damages resulting from the inclusion of Southern Power as a contracting party under these agreements. Alabama Power has guaranteed a $100 million principal amount long-term bank loan SEGCO entered into in 2018 and subsequently extended and amended. Georgia Power has agreed to reimburse Alabama Power for the portion of such obligation corresponding to Georgia Power's proportionate ownership of SEGCO's stock if Alabama Power is called upon to make such payment under its guarantee. At December 31, 2023, the capitalization of SEGCO consisted of $69 million of equity and $100 million of long-term debt that matures in November 2024, on which the annual interest requirement is derived from a variable rate index. SEGCO had no short-term debt outstanding at December 31, 2023. See Note 7 under "SEGCO" for additional information. As discussed in Note 9, Alabama Power and Georgia Power have entered into certain residual value guarantees related to railcar leases.
17. SUBSEQUENT EVENTS Georgia Power Integrated Resource Plans On March 26, 2024, Georgia Power and the staff of the Georgia PSC reached a stipulated agreement for the 2023 IRP Update which Georgia Power expects the Georgia PSC to render a final decision on April 16, 2024. The ultimate outcome of this matter cannot be determined at this time. See Note 2 under "Georgia Power – Integrated Resource Plans" for additional information. Nuclear Construction Cost and Schedule On March 1, 2024, the generator of Unit 4 successfully synchronized to the power grid and generated electricity for the first time. See Note 2 under "Georgia Power – Nuclear Construction" for additional information. General Litigation Matters On March 11, 2024, Georgia Power filed a motion to dismiss certain claims. On March 14, 2024, Georgia Power filed motions for summary judgement. See Note 3 under "Georgia Power" for additional information. Transmission Property Sales In December 2023, Georgia Power requested and subsequent to December 31, 2023, FERC approved the sale of transmission lines under Docket No. AC24-24-000. The sale is expected to be completed during second quarter 2024.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No. | Item (a) | Unrealized Gains and Losses on Available-For-Sale Securities (b) | Minimum Pension Liability Adjustment (net amount) (c) | Foreign Currency Hedges (d) | Other Adjustments (e) | Other Cash Flow Hedges Interest Rate Swaps (f) | Other Cash Flow Hedges [Specify] (g) | Totals for each category of items recorded in Account 219 (h) | Net Income (Carried Forward from Page 116, Line 78) (i) | Total Comprehensive Income (j)
1 | Balance of Account 219 at Beginning of Preceding Year |  |  |  |  | 40,919,777 |  | 40,919,777 |  |
2 | Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income |  |  |  |  | 5,185,289 |  | 5,185,289 |  |
3 | Preceding Quarter/Year to Date Changes in Fair Value |  |  |  |  | 23,255,077 |  | 23,255,077 |  |
4 | Total (lines 2 and 3) |  |  |  |  | 28,440,366 |  | 28,440,366 | 1,813,353,766 | 1,841,794,132
5 | Balance of Account 219 at End of Preceding Quarter/Year |  |  |  |  | 12,479,411 |  | 12,479,411 |  |
6 | Balance of Account 219 at Beginning of Current Year |  |  |  |  | 12,479,411 |  | 12,479,411 |  |
7 | Current Quarter/Year to Date Reclassifications from Account 219 to Net Income |  |  |  |  | 4,588,082 |  | 4,588,082 |  |
8 | Current Quarter/Year to Date Changes in Fair Value |  |  |  |  | 1,586,134 |  | 1,586,134 |  |
9 | Total (lines 7 and 8) |  |  |  |  | 3,001,948 |  | 3,001,948 | 2,079,614,443 | 2,082,616,391
10 | Balance of Account 219 at End of Current Quarter/Year |  |  |  | (a) 0 | 9,477,463 |  | 9,477,463 |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: AccumulatedOtherComprehensiveIncomeLossOtherAdjustmentsToComprehensiveIncomeLossBalance
See Schedules 232 and 278 for gas and electric fair value hedges

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No. | Classification (a) | Total Company For the Current Year/Quarter Ended (b) | Electric (c) | Gas (d) | Other (Specify) (e) | Other (Specify) (f) | Other (Specify) (g) | Common (h)
1 | UtilityPlantAbstract UTILITY PLANT |  |  |  |  |  |  |
2 | UtilityPlantInServiceAbstract In Service |  |  |  |  |  |  |
3 | UtilityPlantInServiceClassified Plant in Service (Classified) | 48,939,001,715 | 48,939,001,715 |  |  |  |  |
4 | UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases | 1,903,583,247 | 1,903,583,247 |  |  |  |  |
5 | UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold |  |  |  |  |  |  |
6 | UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified |  |  |  |  |  |  |
7 | UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified |  |  |  |  |  |  |
8 | UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7) | 50,842,584,962 | 50,842,584,962 |  |  |  |  |
9 | UtilityPlantLeasedToOthers Leased to Others |  |  |  |  |  |  |
10 | UtilityPlantHeldForFutureUse Held for Future Use | 108,050,136 | 108,050,136 |  |  |  |  |
11 | ConstructionWorkInProgress Construction Work in Progress | 4,987,468,923 | 4,987,468,923 |  |  |  |  |
12 | UtilityPlantAcquisitionAdjustment Acquisition Adjustments | 28,251,085 | 28,251,085 |  |  |  |  |
13 | UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12) | 55,966,355,106 | 55,966,355,106 |  |  |  |  |
14 | AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion | 14,000,522,463 | 14,000,522,463 |  |  |  |  |
15 | UtilityPlantNet Net Utility Plant (13 less 14) | 41,965,832,643 | 41,965,832,643 |  |  |  |  |
16 | DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION |  |  |  |  |  |  |
17 | AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service: |  |  |  |  |  |  |
18 | DepreciationUtilityPlantInService Depreciation | 13,400,830,051 | 13,400,830,051 |  |  |  |  |
19 | AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights |  |  |  |  |  |  |
20 | AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights |  |  |  |  |  |  |
21 | AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant | 571,581,226 | 571,581,226 |  |  |  |  |
22 | DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21) | 13,972,411,277 | 13,972,411,277 |  |  |  |  |
23 | DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others |  |  |  |  |  |  |
24 | DepreciationUtilityPlantLeasedToOthers Depreciation |  |  |  |  |  |  |
25 | AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion |  |  |  |  |  |  |
26 | DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25) |  |  |  |  |  |  |
27 | DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use |  |  |  |  |  |  |
28 | DepreciationUtilityPlantHeldForFutureUse Depreciation |  |  |  |  |  |  |
29 | AmortizationUtilityPlantHeldForFutureUse Amortization |  |  |  |  |  |  |
30 | DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29) |  |  |  |  |  |  |
31 | AbandonmentOfLeases Abandonment of Leases (Natural Gas) |  |  |  |  |  |  |
32 | AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment | 28,111,186 | 28,111,186 |  |  |  |  |
33 | AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32) | 14,000,522,463 | 14,000,522,463 |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No. | Description of item (a) | Balance Beginning of Year (b) | Changes during Year Additions (c) | Changes during Year Amortization (d) | Changes during Year Other Reductions (Explain in a footnote) (e) | Balance End of Year (f)
1 | Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1) |  |  |  |  |
2 | Fabrication | 110,998,816 | 74,760,719 |  | (b) 138,519,400 | 47,240,135
3 | Nuclear Materials | 82,971,389 | 40,910,811 |  | (c) 76,684,946 | 47,197,254
4 | Allowance for Funds Used during Construction | 35,438,617 | 14,054,792 |  | (d) 27,041,985 | 22,451,424
5 | (Other Overhead Construction Costs, provide details in footnote) | 8,548,039 | 13,984,286 |  | (e) 15,852,804 | 6,679,521
6 | SUBTOTAL (Total 2 thru 5) | 237,956,861 |  |  | 258,099,135 | 123,568,334
7 | Nuclear Fuel Materials and Assemblies |  |  |  |  |
8 | In Stock (120.2) | 225,452,810 | 258,099,136 |  | (f) 236,604,669 | 246,947,277
9 | In Reactor (120.3) | 480,388,723 | 236,604,669 |  | (g) 150,208,145 | 566,785,247
10 | SUBTOTAL (Total 8 & 9) | 705,841,533 |  |  |  | 813,732,524
11 | Spent Nuclear Fuel (120.4) |  | 150,208,145 |  | (h) 104,789,655 | 45,418,490
12 | Nuclear Fuel Under Capital Leases (120.6) |  |  |  |  |
13 | (Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5) | 340,156,168 |  | (a) 37,398,818 |  | 377,554,986
14 | TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13) | 603,642,226 |  |  |  | 605,164,362
15 | Estimated Net Salvage Value of Nuclear Materials in Line 9 |  |  |  |  |
16 | Estimated Net Salvage Value of Nuclear Materials in Line 11 |  |  |  |  |
17 | Est Net Salvage Value of Nuclear Materials in Chemical Processing |  |  |  |  |
18 | Nuclear Materials held for Sale (157) |  |  |  |  |
19 | Uranium |  |  |  |  |
20 | Plutonium |  |  |  |  |
21 | Other (Provide details in footnote) |  |  |  |  |
22 | TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21) |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForAmortizationOfNuclearFuelAssembliesAmortization
Line 13 - Column D Consists of: |
Amortization Expense | $ | (146,464,295) |
Original Cost of Assets Retired | 109,065,477 |
Transfer of Retired Fuel Assemblies to 120.4 | — |
Total | $ | (37,398,818) |
(b) Concept: FabricationCostsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions
Net Transfers To: |
Stock Account - 120.2 | $ | 138,565,930 |
Reactor Account - 120.3 | (46,530) |
Total | $ | 138,519,400 |
(c) Concept: NuclearMaterialsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions
Net Transfers To: |
Stock Account - 120.2 | $ | 76,684,946 |
Reactor Account - 120.3 | — |
Total | $ | 76,684,946 |
(d) Concept: AllowanceForFundsConstructionNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions
Net Transfers To: |
Stock Account - 120.2 | $ | 27,041,985 |
Reactor Account - 120.3 | — |
Total | $ | 27,041,985 |
(e) Concept: OtherOverheadConstructionCostsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions
Net Transfers To: |
Stock Account - 120.2 | $ | 15,855,281 |
Reactor Account - 120.3 | (2,478) |
Total | $ | 15,852,803 |
(f) Concept: NuclearFuelMaterialsAndAssembliesInStockOtherReductions
Transfers of: |
Completed Assemblies to Reactor Account 120.3 | $ | 236,604,669 |
(g) Concept: NuclearFuelAssembliesInReactorOtherReductions
Transfers of: |
Completed Burn Assembly to Spent Fuel 120.4 | $ | 150,208,145 |
(h) Concept: SpentNuclearFuelOtherReductions
Transfers of: |
Retired Assemblies to 120.5 | $ | 104,789,655 |
Transfer of Retired Fuel Assemblies to 120.3 | — |
Total | $ | 104,789,655 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No. | Account (a) | Balance Beginning of Year (b) | Additions (c) | Retirements (d) | Adjustments (e) | Transfers (f) | Balance at End of Year (g)
1 | 1. INTANGIBLE PLANT |  |  |  |  |  |
2 | (301) Organization | 45,130 |  |  |  |  | 45,130
3 | (302) Franchise and Consents | 40,900,343 |  |  |  |  | 40,900,343
4 | (303) Miscellaneous Intangible Plant | 699,876,271 | 87,836,202 | 2,413,157 |  |  | 785,299,316
5 | TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) | 740,821,744 | 87,836,202 | 2,413,157 |  |  | 826,244,789
6 | 2. PRODUCTION PLANT |  |  |  |  |  |
7 | A. Steam Production Plant |  |  |  |  |  |
8 | (310) Land and Land Rights | 48,147,168 |  | 17,631 |  |  | 48,129,537
9 | (311) Structures and Improvements | 813,600,710 | 27,288,368 | 2,415,319 |  |  | 783,897,023
10 | (312) Boiler Plant Equipment | 5,345,623,144 | 183,998,300 | 49,023,521 |  |  | 5,480,597,923
11 | (313) Engines and Engine-Driven Generators |  |  |  |  |  |
12 | (314) Turbogenerator Units | 535,185,772 | 9,335,224 | 3,388,350 |  |  | 541,132,646
13 | (315) Accessory Electric Equipment | 183,895,310 | 7,728,023 | 945,940 |  |  | 190,677,393
14 | (316) Misc. Power Plant Equipment | 23,741,216 | 5,824,161 | 15,936,320 |  |  | 45,501,697
15 | (317) Asset Retirement Costs for Steam Production | 910,493,735 | 98,239,661 | 65,266,399 |  |  | 746,987,675
16 | TOTAL Steam Production Plant (Enter Total of lines 8 thru 15) | 7,860,687,055 | 81,357,679 | 105,120,840 |  |  | 7,836,923,894
17 | B. Nuclear Production Plant |  |  |  |  |  |
18 | (320) Land and Land Rights | 1,095,252 |  | 7,358 |  |  | 1,087,894
19 | (321) Structures and Improvements | 1,387,140,724 | 4,569,660,319 | 3,255,030 |  |  | 5,953,546,013
20 | (322) Reactor Plant Equipment | 2,162,933,990 | 64,780,294 | 21,983,498 |  |  | 2,205,730,786
21 | (323) Turbogenerator Units | 624,085,351 | 17,842,893 | 16,411,335 |  |  | 625,516,909
22 | (324) Accessory Electric Equipment | 539,906,056 | 8,700,528 | 4,103,081 |  |  | 544,503,503
23 | (325) Misc. Power Plant Equipment | 228,855,196 | 9,554,093 | 5,744,818 |  |  | 232,664,471
24 | (326) Asset Retirement Costs for Nuclear Production | 295,533,775 | 89,480,043 | 1,648,895 |  |  | 386,662,713
25 | TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24) | 5,239,550,344 | 4,760,018,170 | 49,856,225 |  |  | 9,949,712,289
26 | C. Hydraulic Production Plant |  |  |  |  |  |
27 | (330) Land and Land Rights | 36,327,260 | 2,644,667 | 3,294,275 |  |  | 35,677,652
28 | (331) Structures and Improvements | 133,341,047 | 6,550,970 | 680,357 |  |  | 139,211,660
29 | (332) Reservoirs, Dams, and Waterways | 333,434,187 | 8,858,215 | 1,194,201 |  |  | 341,098,201
30 | (333) Water Wheels, Turbines, and Generators | 293,837,865 | 32,848,488 | 6,307,877 |  |  | 320,378,476
31 | (334) Accessory Electric Equipment | 53,179,692 | 15,917,175 | 2,124,827 |  |  | 66,972,040
32 | (335) Misc. Power Plant Equipment | 30,028,128 | 9,752,276 | 519,838 |  |  | 40,300,242
33 | (336) Roads, Railroads, and Bridges | 7,103,324 | 1,362,185 | 1,871 |  |  | 8,463,638
34 | (337) Asset Retirement Costs for Hydraulic Production | 6,510,740 |  | 17,129 |  |  | 6,493,611
35 | TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34) | 893,762,243 | 77,933,976 | 13,100,699 |  |  | 958,595,520
36 | D. Other Production Plant |  |  |  |  |  |
37 | (340) Land and Land Rights | 37,003,665 |  |  |  |  | 37,003,665
38 | (341) Structures and Improvements | 1,867,893,223 | 25,050,466 | 1,224,345 |  |  | 1,891,719,344
39 | (342) Fuel Holders, Products, and Accessories | 86,542,920 | 4,215,147 | 1,054,264 |  |  | 89,703,803
40 | (343) Prime Movers | 1,692,741,415 | 212,563,195 | 156,784,626 |  |  | 1,748,519,984
41 | (344) Generators | 1,260,455,120 | 15,465,981 | 17,562,300 |  |  | 1,258,358,801
42 | (345) Accessory Electric Equipment | 153,360,653 | 6,197,857 | 846,609 |  |  | 160,405,119
43 | (346) Misc. Power Plant Equipment | 42,716,644 | 1,685,049 | 921,298 |  |  | 43,480,395
44 | (347) Asset Retirement Costs for Other Production | 49,988,035 |  |  |  |  | 49,988,035
44.1 | (348) Energy Storage Equipment - Production |  |  |  |  |  |
45 | TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44) | 5,190,701,675 | 265,177,695 | 176,700,224 |  |  | 5,279,179,146
46 | TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45) | 19,184,701,317 | 5,184,487,520 | 344,777,988 |  |  | 24,024,410,849
47 | 3. Transmission Plant |  |  |  |  |  |
48 | (350) Land and Land Rights | 432,958,083 | 44,896,346 | 5,016,294 |  |  | 472,838,135
48.1 | (351) Energy Storage Equipment - Transmission |  |  |  |  |  |
49 | (352) Structures and Improvements | 264,348,896 | 74,305,124 | 212,049 |  |  | 338,441,971
50 | (353) Station Equipment | 2,931,761,827 | 324,319,749 | 29,623,423 |  |  | 3,226,458,153
51 | (354) Towers and Fixtures | 1,141,277,424 | 183,987,901 | 7,617,505 |  |  | 1,317,647,820
52 | (355) Poles and Fixtures | 888,123,412 | 7,178,300 | 34,169,298 |  |  | 846,775,814
53 | (356) Overhead Conductors and Devices | 1,781,066,392 | 321,106,544 | 43,605,765 |  |  | 2,058,567,171
54 | (357) Underground Conduit | 11,851,603 |  |  |  |  | 11,851,603
55 | (358) Underground Conductors and Devices | 23,197,202 | 2,633,055 | 119,730 |  |  | 25,710,527
56 | (359) Roads and Trails | 14,899,895 | 2,285,475 | 65,402 |  |  | 17,119,968
57 | (359.1) Asset Retirement Costs for Transmission Plant | 907,570 |  | 58,576 |  |  | 848,994
58 | TOTAL Transmission Plant (Enter Total of lines 48 thru 57) | 7,488,577,164 | 946,355,894 | 120,370,890 |  |  | 8,314,562,168
59 | 4. Distribution Plant |  |  |  |  |  |
60 | (360) Land and Land Rights | 222,331,175 | 80,303,963 | 22,062 |  |  | 302,613,076
61 | (361) Structures and Improvements | 286,805,271 | 65,507,081 | 163,706 |  |  | 352,148,646
62 | (362) Station Equipment | 1,963,226,226 | 278,907,681 | 7,864,025 |  |  | 2,234,269,882
63 | (363) Energy Storage Equipment – Distribution |  |  |  |  |  |
64 | (364) Poles, Towers, and Fixtures | 1,410,583,617 | 209,846,987 | 69,019,908 |  |  | 1,551,410,696
65 | (365) Overhead Conductors and Devices | 1,671,077,514 | 270,149,474 | 17,725,413 |  |  | 1,923,501,575
66 | (366) Underground Conduit | 590,663,706 | 64,630,075 | 3,350,911 |  |  | 651,942,870
67 | (367) Underground Conductors and Devices | 2,795,459,128 | 351,370,722 | 11,891,909 |  |  | 3,134,937,941
68 | (368) Line Transformers | 1,995,410,295 | 171,317,021 | 10,332,280 |  |  | 2,156,395,036
69 | (369) Services | 1,239,835,613 | 47,748,512 | 2,201,274 |  |  | 1,285,382,851
70 | (370) Meters | 546,368,683 | 32,938,242 | 3,327,036 |  |  | 575,979,889
71 | (371) Installations on Customer Premises | 11,583,146 | 18,588,548 | 960,608 |  |  | 29,211,086
72 | (372) Leased Property on Customer Premises | 798,128 |  |  |  |  | 798,128
73 | (373) Street Lighting and Signal Systems | 1,052,431,046 | 127,093,842 | 29,743,083 |  |  | 1,149,781,805
74 | (374) Asset Retirement Costs for Distribution Plant | 436,613 |  | 15,588 |  |  | 452,201
75 | TOTAL Distribution Plant (Enter Total of lines 60 thru 74) | 13,787,010,161 | 1,718,402,148 | 156,586,627 |  |  | 15,348,825,682
76 | 5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT |  |  |  |  |  |
77 | (380) Land and Land Rights |  |  |  |  |  |
78 | (381) Structures and Improvements |  |  |  |  |  |
79 | (382) Computer Hardware |  |  |  |  |  |
80 | (383) Computer Software |  |  |  |  |  |
81 | (384) Communication Equipment |  |  |  |  |  |
82 | (385) Miscellaneous Regional Transmission and Market Operation Plant |  |  |  |  |  |
83 | (386) Asset Retirement Costs for Regional Transmission and Market Oper |  |  |  |  |  |
84 | TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83) |  |  |  |  |  |
85 | 6. General Plant |  |  |  |  |  |
86 | (389) Land and Land Rights | 34,366,338 | 2,545,174 | 957,857 |  |  | 35,953,655
87 | (390) Structures and Improvements | 817,968,864 | 66,529,129 | 10,203,338 |  |  | 874,294,655
88 | (391) Office Furniture and Equipment | 106,730,683 | 20,691,567 | 997,036 |  |  | 126,425,214
89 | (392) Transportation Equipment | 421,777,874 | 25,529,103 | 15,386,894 |  |  | 431,920,083
90 | (393) Stores Equipment | 4,534,265 | 11,434,357 |  |  |  | 15,968,622
91 | (394) Tools, Shop and Garage Equipment | 84,022,114 | 6,374,915 | 30,852 |  |  | 90,366,177
92 | (395) Laboratory Equipment | 66,841,465 | 4,187,545 |  |  |  | 71,029,010
93 | (396) Power Operated Equipment | 34,046,836 | 19,235,290 | 2,728,883 |  |  | 50,553,243
94 | (397) Communication Equipment | 514,988,271 | 68,974,785 | 6,260,798 |  |  | 577,702,258
95 | (398) Miscellaneous Equipment | 41,555,406 | 18,144,700 | 43,728 |  |  | 59,656,378
96 | SUBTOTAL (Enter Total of lines 86 thru 95) | 2,126,832,116 | 243,646,565 | 36,609,386 |  |  | 2,333,869,295
97 | (399) Other Tangible Property |  |  |  |  |  |
98 | (399.1) Asset Retirement Costs for General Plant | 7,143,029 |  | 1,815,208 |  |  | 5,327,821
99 | TOTAL General Plant (Enter Total of lines 96, 97, and 98) | 2,119,689,087 | 243,646,565 | 34,794,178 |  |  | 2,328,541,474
100 | TOTAL (Accounts 101 and 106) | 43,320,799,473 | 8,180,728,329 | 658,942,840 |  |  | 50,842,584,962
101 | (102) Electric Plant Purchased (See Instr. 8) |  |  |  |  |  |
102 | (Less) (102) Electric Plant Sold (See Instr. 8) |  |  |  |  |  |
103 | (103) Experimental Plant Unclassified |  |  |  |  |  |
104 | TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103) | 43,320,799,473 | 8,180,728,329 | 658,942,840 |  |  | (a) 50,842,584,962

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: ElectricPlantInService
Plant-in-service balances include the following lease balances:
| Plant in Service
Capital Leases: |
Other Production | $ | 273,829,315 |
General | 89,557,330 |
| $ | 363,386,645 |
Operating Leases: |
Steam Production | $ | 46,776,438 |
Other Production | 1,437,316,201 |
Nuclear Production | 457,054 |
General | 55,646,909 |
| $ | 1,540,196,602 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No. | LesseeName Name of Lessee (a) | IndicationOfAssociatedCompany * (Designation of Associated Company) (b) | LeaseDescription Description of Property Leased (c) | CommissionAuthorization Commission Authorization (d) | ExpirationDateOfLease Expiration Date of Lease (e) | ElectricPlantLeasedToOthers Balance at End of Year (f)
1 |  |  |  |  |  |
2 |  |  |  |  |  |
3 |  |  |  |  |  |
4 |  |  |  |  |  |
5 |  |  |  |  |  |
6 |  |  |  |  |  |
7 |  |  |  |  |  |
8 |  |  |  |  |  |
9 |  |  |  |  |  |
10 |  |  |  |  |  |
11 |  |  |  |  |  |
12 |  |  |  |  |  |
13 |  |  |  |  |  |
14 |  |  |  |  |  |
15 |  |  |  |  |  |
16 |  |  |  |  |  |
17 |  |  |  |  |  |
18 |  |  |  |  |  |
19 |  |  |  |  |  |
20 |  |  |  |  |  |
21 |  |  |  |  |  |
22 |  |  |  |  |  |
23 |  |  |  |  |  |
24 |  |  |  |  |  |
25 |  |  |  |  |  |
26 |  |  |  |  |  |
27 |  |  |  |  |  |
28 |  |  |  |  |  |
29 |  |  |  |  |  |
30 |  |  |  |  |  |
31 |  |  |  |  |  |
32 |  |  |  |  |  |
33 |  |  |  |  |  |
34 |  |  |  |  |  |
35 |  |  |  |  |  |
36 |  |  |  |  |  |
37 |  |  |  |  |  |
38 |  |  |  |  |  |
39 |  |  |  |  |  |
40 |  |  |  |  |  |
41 |  |  |  |  |  |
42 |  |  |  |  |  |
43 |  |  |  |  |  |
44 |  |  |  |  |  |
45 |  |  |  |  |  |
46 |  |  |  |  |  |
47 | TOTAL |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No. | ElectricPlantHeldForFutureUseDescription Description and Location of Property (a) | ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b) | ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c) | ElectricPlantHeldForFutureUse Balance at End of Year (d)
1 | Land and Rights: |  |  |
2 | Dawson Crossing-S Dahlonega 500kv T/L | 12/01/2008 | 12/31/2040 | 10,543,832
3 | New Hampstead Substation | 06/30/2009 | 12/31/2040 | 53,836
4 | S Dahlonega-Clermont Jct 500kv T/L | 09/30/2009 | 12/31/2040 | 28,188,653
5 | S Dahlonega-Clermont Jct 230kv T/L | 09/30/2009 | 12/31/2040 | 17,268,413
6 | Bethabara-E. Walton 230kv T/L Site | 03/31/2011 | 12/31/2040 | 3,708,308
7 | Piedmont Substation Site | 03/31/2011 | 12/31/2040 | 12,933,362
8 | Boyd Ave Substation Site | 08/31/2012 | 12/31/2040 | 1,334,192
9 | Stewart County | 09/01/2012 | (a) 12/31/2030 | 22,647,107
10 | McDonough-East Point 230 KV | 09/01/2014 | 12/31/2040 | 89,188
11 | Utoy Springs Substation Site | 09/01/2014 | 12/31/2040 | 594,185
12 | Wallace Dam - Klondike 500 KV | 09/01/2014 | 12/31/2031 | 3,628,989
13 | South Hall - Winder T/L | 09/01/2014 | 12/31/2035 | 883,035
14 | Medical Arts Substation Site | 02/01/2017 | 12/31/2026 | 1,236,065
15 | Savannah Portside International- Old River Road Substation Site | 08/01/2018 | 12/31/2040 | 30,266
16 | Northwest Region Operating HQ Site | 10/01/2019 | 12/31/2024 | 529,886
17 | Lewiston Road Substation Site | 03/01/2020 | 12/31/2025 | 1,968,390
18 | McGrau Ford BESS Site | 12/01/2023 | 12/31/2025 | 2,412,429
21 | Other Property: |  |  |
22 |  |  |  |
23 |  |  |  |
24 |  |  |  |
25 |  |  |  |
26 |  |  |  |
27 |  |  |  |
28 |  |  |  |
29 |  |  |  |
30 |  |  |  |
31 |  |  |  |
32 |  |  |  |
33 |  |  |  |
34 |  |  |  |
35 |  |  |  |
36 |  |  |  |
37 |  |  |  |
38 |  |  |  |
39 |  |  |  |
40 |  |  |  |
41 |  |  |  |
42 |  |  |  |
43 |  |  |  |
44 |  |  |  |
45 |  |  |  |
46 |  |  |  |
47 | TOTAL |  |  | 108,050,136

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
The earliest date this is expected to be in service is 12/31/2030.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No. | ConstructionWorkInProgressProjectDescription Description of Project (a) | ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1 | Plant Vogtle Units 3&4 Construction | 3,321,939,142
2 | Plant Bowen - Clean Air Compliance | 65,170,906
3 | Plant Bowen - Miscellaneous Additions | 10,131,185
4 | Plant Scherer - Outage Projects | 1,113,357
5 | Plant Hatch - Controls | 13,967,125
6 | Plant Hatch - Electrical | 8,213,627
7 | Plant Hatch - Mechanical | 1,060,523
8 | Plant Hatch - Miscellaneous Additions | 11,498,556
9 | Plant Vogtle 1&2 - Controls | 6,518,169
10 | Plant Vogtle 1&2 - Miscellaneous Additions | 50,952,361
11 | Chattahoochee Hydro Miscellaneous Additions | 89,725,326
12 | Ferc Relicensing Various Hydro Plants | 4,095,973
13 | North Georgia Hydro Miscellaneous Additions | 51,640,859
14 | Plant Mcintosh - Outage Projects | 13,759,764
15 | Plant McIntosh - Miscellaneous Additions | 1,454,144
16 | Plant McDonough - Miscellaneous Additions | 8,769,783
17 | Plant Wilson CT - Miscellaneous Additions | 1,890,015
18 | Solar Self Build Projects | 78,604,142
19 | Distribution New Business | 94,482,319
20 | Outdoor Lighting Projects | 6,229,754
21 | Miscellaenous Transmission Line Replacements | 20,698,432
22 | Miscellaneous Transmission Line Additions & Improvements | 23,312,045
23 | Miscellaneous Transmission Substation Additions & Improvements | 20,284,590
24 | Miscellaneous Transmission Transformer Replacement | 3,283,366
25 | Miscellaneous Distribution Line Improvements | 6,854,763
26 | Miscellaneous Distribution Substation Additions & Improvements | 42,837,122
27 | Grid Investment | 205,825,676
28 | Substation Reliability Improvements | 40,424,148
29 | Distribution Projects Contribution In Aid Of Construction Offset | 16,199,455
30 | Protective Relay Modernization Project | 19,417,019
31 | Distribution Network Improvements - Miscellaneous | 33,951,297
32 | Overstressed Or Obsolete Circuit Switcher Replacement | 15,805,854
33 | Spare Equipment Stock | 49,653,925
34 | Underground Addition & Improvements | 7,294,122
35 | Doraville Balance of Substation Upgrades | 3,347,451
36 | CBM Monitor Deployment | 21,000,429
37 | Transmission Line Hwy Change | 3,644,038
38 | ROW Services Perfection | 5,714,364
39 | Enterprise Solutions System Upgrades | 4,713,336
40 | Power Delivery Software Upgrades | 3,099,294
41 | Fiber Optics Spurs Construction | 83,197,611
42 | Communications Improvements | 1,858,074
43 | Customer Service Operations Cyber Security | 18,194,974
44 | Converged Network Upgrades | 1,419,665
45 | Generation Software Upgrades | 3,673,691
46 | Customer Service System (CSS) Upgrades | 6,567,310
47 | Building Additions & Improvements | 3,073,273
48 | Capital Maintenance / Asset Management | 24,074,791
49 | Commitments | 12,575,168
50 | Facility | 27,719,384
51 | Intangible | 7,914,609
52 | Load Related System Improvements | 11,445,898
53 | Miscellaneous | 178,863,005
54 | New Business | 102,935,944
55 | Other General Plant | 56,775,091
56 | Software Purchases and Upgrades | 102,254,945
57 | Technology | 26,462,544
58 | Plant Bowen - Air | 2,329,017
59 | Plant Yates - Water | 3,098,873
60 | Grid Modernization | 1,714,920
61 | Outage | 2,243,824
62 | Plant Scherer - Water | 4,696,903
63 | Reliability | 11,230,354
64 | Replace Failed Equipment | 6,026,518
65 | Solar | 13,568,411
66 | System Flow Projects | 20,538,902
67 | System Operations - Study Driven - Generation Changes | 23,760,778
68 | Unassigned | 3,590,039
69 | Misc GSU | 2,680,806
70 | Miscellaneous Minor Projects (Less Than $1 Million) | 41,107,251
71 | Reserve for Future Capital Spend | 206,701,406
43 | Total | 4,987,468,923

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No. | Item (a) | Total (c + d + e) (b) | Electric Plant in Service (c) | Electric Plant Held for Future Use (d) | Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1 | AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year | 12,619,134,167 | 12,619,134,167 |  |
2 | Depreciation Provisions for Year, Charged to |  |  |  |
3 | DepreciationExpenseExcludingAdjustments (403) Depreciation Expense | 1,335,454,797 | 1,335,454,797 |  |
4 | DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs | 29,215,684 | 29,215,684 |  |
5 | ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others |  |  |  |
6 | TransportationExpensesClearing Transportation Expenses-Clearing | 23,278,573 | 23,278,573 |  |
7 | OtherClearingAccounts Other Clearing Accounts | 131,576,882 | 131,576,882 |  |
8 | OtherAccounts Other Accounts (Specify, details in footnote): |  |  |  |
9.1 | Other Accounts (Specify, details in footnote): | 164,379,821 | (a) 164,379,821 |  |
10 | DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9) | 1,683,905,757 | 1,683,905,757 |  |
11 | Net Charges for Plant Retired: |  |  |  |
12 | BookCostOfRetiredPlant Book Cost of Plant Retired | 656,541,480 | (b) 656,541,480 |  |
13 | CostOfRemovalOfPlant Cost of Removal | 339,735,541 | 339,735,541 |  |
14 | SalvageValueOfRetiredPlant Salvage (Credit) | 92,394,390 | 92,394,390 |  |
15 | NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14) | 903,882,631 | 903,882,631 |  |
16 | OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote): |  |  |  |
17.1 | Other Debit or Cr. Items (Describe, details in footnote): | 1,672,758 | (c) 1,672,758 |  |
18 | BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired |  |  |  |
19 | AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18) | (d) 13,400,830,051 | (e) 13,400,830,051 |  |
Section B. Balances at End of Year According to Functional Classification
20 | AccumulatedDepreciationSteamProduction Steam Production | 2,960,755,356 | 2,960,755,356 |  |
21 | AccumulatedDepreciationNuclearProduction Nuclear Production | 3,042,219,340 | 3,042,219,340 |  |
22 | AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional | 2,329,840,356 | 2,329,840,356 |  |
23 | AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage | 2,824,451,656 | 2,824,451,656 |  |
24 | AccumulatedDepreciationOtherProduction Other Production | 993,866,759 | 993,866,759 |  |
25 | AccumulatedDepreciationTransmission Transmission | 1,365,055,274 | 1,365,055,274 |  |
26 | AccumulatedDepreciationDistribution Distribution | 3,610,995,972 | 3,610,995,972 |  |
27 | AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation |  |  |  |
28 | AccumulatedDepreciationGeneral General | 933,326,050 | 933,326,050 |  |
29 | AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28) | (f) 13,400,830,051 | (g) 13,400,830,051 |  |

FOOTNOTE DATA

(a) Concept: OtherAccounts
Reflects provision of Account 108 related to capital/operating leases not recorded to Account 403
| Depreciation Expense
Capital Leases: |
Other Production | $ | 16,798,351 |
General | — |
| $ | 16,798,351 |
Operating Leases: |
Steam Production | $ | 6,279,424 |
Nuclear Production | 173,577 |
Other Production | 133,426,919 |
General | 7,701,550 |
| $ | 147,581,470 |
(b) Concept: BookCostOfRetiredPlant
Variance between Schedule Page 204-207 Line No.:100 Column: d and Schedule Page 219 Line No.: 12 Column: c is due to the exclusion of intangible plant retirements on Page 219 for $2,401,360.
(c) Concept: OtherAdjustmentsToAccumulatedDepreciation
Reflects retired plant net book values moved to FERC 182 Deferred Debits and gain/loss resulting from retirements of operating leases.
(d) Concept: AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Accumulated depreciation balances include the following lease balances:
| Accumulated Depreciation
Capital Leases: |
Other Production | $ | (95,192,638) |
General | (64,530,898) |
| $ | (159,723,536) |
Operating Leases: |
Steam Production | $ | (23,912,653) |
Nuclear Production | (122,922) |
Other Production | (610,188,895) |
General | (22,143,038) |
| $ | (656,367,508) |
(e) Concept: AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Accumulated depreciation balances include the following lease balances:
| Accumulated Depreciation
Capital Leases: |
Other Production | $ | (95,192,638) |
General | (64,530,898) |
| $ | (159,723,536) |
Operating Leases: |
Steam Production | $ | (23,912,653) |
Nuclear Production | (122,922) |
Other Production | (610,188,895) |
General | (22,143,038) |
| $ | (656,367,508) |
(f) Concept: AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Accumulated depreciation balances include the following lease balances:
| Accumulated Depreciation
Capital Leases: |
Other Production | $ | (95,192,638) |
General | (64,530,898) |
| $ | (159,723,536) |
Operating Leases: |
Steam Production | $ | (23,912,653) |
Nuclear Production | (122,922) |
Other Production | (610,188,895) |
General | (22,143,038) |
| $ | (656,367,508) |
(g) Concept: AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Accumulated depreciation balances include the following lease balances:
| Accumulated Depreciation
Capital Leases: |
Other Production | $ | (95,192,638) |
General | (64,530,898) |
| $ | (159,723,536) |
Operating Leases: |
Steam Production | $ | (23,912,653) |
Nuclear Production | (122,922) |
Other Production | (610,188,895) |
General | (22,143,038) |
| $ | (656,367,508) |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No. | DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a) | DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b) | DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c) | InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d) | EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e) | InterestAndDividendRevenueFromInvestments Revenues for Year (f) | InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g) | InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1 | Southern Electric Generating Co. |  |  |  |  |  |  |
2 | Common Stock - 90,000 shares | 02/11/1959 |  | 9,000,000 |  |  | 9,000,000 |
3 | Common Stock - 45,000 shares | 01/25/1960 |  | 4,500,000 |  |  | 4,500,000 |
4 | Common Stock - 23,000 shares | 08/28/1969 |  | 2,300,000 |  |  | 2,300,000 |
5 | Common Stock - 6,000 shares | 09/23/1968 |  | 600,000 |  |  | 600,000 |
6 | Equity in Undistributed Earnings |  |  | 23,599,758 | 6,141,773 | 11,410,127 | 18,331,404 |
7 | Piedmont Forrest Corporation |  |  |  |  |  |  |
8 | Common Stock - 100,000 shares | 11/17/1977 |  | 100,000 |  |  | 100,000 |
9 | Other Paid-in-Capital |  |  |  |  |  |  |
10 | Equity in Undistributed Earnings |  |  | 17,129,976 | 967,807 | 529,979 | 17,567,804 |
11 | Advances from Parent (open account) |  |  | 111,552 |  | 111,552 |  |
42 | Total Cost of Account 123.1 $ 16,500,000 |  | Total | 57,341,286 | 7,109,580 | 12,051,658 | 52,399,208 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No. | Account (a) | Balance Beginning of Year (b) | Balance End of Year (c) | Department or Departments which Use Material (d)
1 | Fuel Stock (Account 151) | 281,851,393 | 468,132,742 | Electric
2 | Fuel Stock Expenses Undistributed (Account 152) | 2,315,874 | 4,961,210 |
3 | Residuals and Extracted Products (Account 153) |  |  |
4 | Plant Materials and Operating Supplies (Account 154) |  |  |
5 | Assigned to - Construction (Estimated) |  |  |
6 | Assigned to - Operations and Maintenance |  |  |
7 | Production Plant (Estimated) | 430,893,064 | 465,007,514 | Electric
8 | Transmission Plant (Estimated) | 123,759,934 | 174,985,475 | Electric
9 | Distribution Plant (Estimated) | 168,633,384 | 237,675,943 | Electric
10 | Regional Transmission and Market Operation Plant (Estimated) |  |  |
11 | Assigned to - Other (provide details in footnote) | (a) 4,882,775 | (b) 5,332,731 | Electric
12 | TOTAL Account 154 (Enter Total of lines 5 thru 11) | 728,169,157 | 883,001,663 |
13 | Merchandise (Account 155) |  |  |
14 | Other Materials and Supplies (Account 156) | 389,375 | 263,239 | Electric
15 | Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util) |  |  |
16 | Stores Expense Undistributed (Account 163) | 45,306 | 12,811 |
17 |  |  |  |
18 |  |  |  |
19 |  |  |  |
20 | TOTAL Materials and Supplies | 1,010,364,619 | 1,351,410,455 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther
Assigned to Other: |
| 12/31/2022
First Aid & Safety | $ | 1,605,284 |
Automotive | 1,754,327 |
In-transit | 1,397,929 |
Construction materials | 125,235 |
| $ | 4,882,775 |
(b) Concept: PlantMaterialsAndOperatingSuppliesOther
Assigned to Other: |
| 12/31/2023
First Aid & Safety | $ | 1,791,764 |
Automotive | 1,898,921 |
In-transit | 1,510,309 |
Construction materials | 131,737 |
| $ | 5,332,731 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
|  | Current Year | Year One | Year Two | Year Three | Future Years | Totals
Line No. | SO2 Allowances Inventory (Account 158.1) (a) | No. (b) | Amt. (c) | No. (d) | Amt. (e) | No. (f) | Amt. (g) | No. (h) | Amt. (i) | No. (j) | Amt. (k) | No. (l) | Amt. (m)
1 | Balance-Beginning of Year | 3,955,008 | 7,239,520 |  |  |  |  |  |  |  |  | 3,955,008 | 7,239,520
2 |  |  |  |  |  |  |  |  |  |  |  |  |
3 | Acquired During Year: |  |  |  |  |  |  |  |  |  |  |  |
4 | Issued (Less Withheld Allow) | 497,251 |  |  |  |  |  |  |  |  |  | 497,251 |
5 | Returned by EPA |  |  |  |  |  |  |  |  |  |  |  |
6 |  |  |  |  |  |  |  |  |  |  |  |  |
7 |  |  |  |  |  |  |  |  |  |  |  |  |
8 | Purchases/Transfers: |  |  |  |  |  |  |  |  |  |  |  |
9 |  |  |  |  |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |  |  |  |  |
11 |  |  |  |  |  |  |  |  |  |  |  |  |
12 |  |  |  |  |  |  |  |  |  |  |  |  |
13 |  |  |  |  |  |  |  |  |  |  |  |  |
14 |  |  |  |  |  |  |  |  |  |  |  |  |
15 | Total |  |  |  |  |  |  |  |  |  |  |  |
16 |  |  |  |  |  |  |  |  |  |  |  |  |
17 | Relinquished During Year: |  |  |  |  |  |  |  |  |  |  |  |
18 | Charges to Account 509 | 15,377 | 15,569 |  |  |  |  |  |  |  |  | 15,377 | 15,569
19 | Other: |  |  |  |  |  |  |  |  |  |  |  |
20 | Allowances Used |  |  |  |  |  |  |  |  |  |  |  |
20.1 | Allowances Used |  |  |  |  |  |  |  |  |  |  |  |
21 | Cost of Sales/Transfers: |  |  |  |  |  |  |  |  |  |  |  |
22 | Adjustment |  |  |  |  |  |  |  |  |  |  |  |
23 |  |  |  |  |  |  |  |  |  |  |  |  |
24 |  |  |  |  |  |  |  |  |  |  |  |  |
25 |  |  |  |  |  |  |  |  |  |  |  |  |
26 |  |  |  |  |  |  |  |  |  |  |  |  |
27 |  |  |  |  |  |  |  |  |  |  |  |  |
28 | Total |  |  |  |  |  |  |  |  |  |  |  |
29 | Balance-End of Year | 4,436,882 | 7,223,951 |  |  |  |  |  |  |  |  | 4,436,882 | 7,223,951
30 |  |  |  |  |  |  |  |  |  |  |  |  |
31 | Sales: |  |  |  |  |  |  |  |  |  |  |  |
32 | Net Sales Proceeds(Assoc. Co.) |  |  |  |  |  |  |  |  |  |  |  |
33 | Net Sales Proceeds (Other) |  |  |  |  |  |  |  |  |  |  |  |
34 | Gains |  |  |  |  |  |  |  |  |  |  |  |
35 | Losses |  |  |  |  |  |  |  |  |  |  |  |
| Allowances Withheld (Acct 158.2) |  |  |  |  |  |  |  |  |  |  |  |
36 | Balance-Beginning of Year |  |  |  |  |  |  |  |  |  |  |  |
37 | Add: Withheld by EPA | 9,066 | 201 |  |  |  |  |  |  |  |  | 9,066 | 201
38 | Deduct: Returned by EPA | 9,066 | 201 |  |  |  |  |  |  |  |  | 9,066 | 201
39 | Cost of Sales |  |  |  |  |  |  |  |  |  |  |  |
40 | Balance-End of Year |  |  |  |  |  |  |  |  |  |  |  |
41 |  |  |  |  |  |  |  |  |  |  |  |  |
42 | Sales |  |  |  |  |  |  |  |  |  |  |  |
43 | Net Sales Proceeds (Assoc. Co.) |  |  |  |  |  |  |  |  |  |  |  |
44 | Net Sales Proceeds (Other) |  |  |  |  |  |  |  |  |  |  |  |
45 | Gains |  |  |  |  |  |  |  |  |  |  |  |
46 | Losses |  |  |  |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
|  | Current Year | Year One | Year Two | Year Three | Future Years | Totals
Line No. | NOx Allowances Inventory (Account 158.1) (a) | No. (b) | Amt. (c) | No. (d) | Amt. (e) | No. (f) | Amt. (g) | No. (h) | Amt. (i) | No. (j) | Amt. (k) | No. (l) | Amt. (m)
1 | Balance-Beginning of Year | 257,133 |  |  |  |  |  |  |  |  |  | 257,133 |
2 |  |  |  |  |  |  |  |  |  |  |  |  |
3 | Acquired During Year: |  |  |  |  |  |  |  |  |  |  |  |
4 | Issued (Less Withheld Allow) | 70,147 |  |  |  |  |  |  |  |  |  | 70,147 |
5 | Returned by EPA |  |  |  |  |  |  |  |  |  |  |  |
6 |  |  |  |  |  |  |  |  |  |  |  |  |
7 |  |  |  |  |  |  |  |  |  |  |  |  |
8 | Purchases/Transfers: |  |  |  |  |  |  |  |  |  |  |  |
9 |  |  |  |  |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |  |  |  |  |
11 |  |  |  |  |  |  |  |  |  |  |  |  |
12 |  |  |  |  |  |  |  |  |  |  |  |  |
13 |  |  |  |  |  |  |  |  |  |  |  |  |
14 |  |  |  |  |  |  |  |  |  |  |  |  |
15 | Total |  |  |  |  |  |  |  |  |  |  |  |
16 |  |  |  |  |  |  |  |  |  |  |  |  |
17 | Relinquished During Year: |  |  |  |  |  |  |  |  |  |  |  |
18 | Charges to Account 509 | 15,004 |  |  |  |  |  |  |  |  |  | 15,004 |
19 | Other: |  |  |  |  |  |  |  |  |  |  |  |
20 | Allowances Used |  |  |  |  |  |  |  |  |  |  |  |
20.1 | Allowances Used |  |  |  |  |  |  |  |  |  |  |  |
21 | Cost of Sales/Transfers: |  |  |  |  |  |  |  |  |  |  |  |
22 | Adjustment |  |  |  |  |  |  |  |  |  |  |  |
23 | Associated Sales – Mississippi Power Company | 129 |  |  |  |  |  |  |  |  |  | 129 |
24 |  |  |  |  |  |  |  |  |  |  |  |  |
25 |  |  |  |  |  |  |  |  |  |  |  |  |
26 |  |  |  |  |  |  |  |  |  |  |  |  |
27 |  |  |  |  |  |  |  |  |  |  |  |  |
28 | Total | 129 |  |  |  |  |  |  |  |  |  | 129 |
29 | Balance-End of Year | 312,147 |  |  |  |  |  |  |  |  |  | 312,147 |
30 |  |  |  |  |  |  |  |  |  |  |  |  |
31 | Sales: |  |  |  |  |  |  |  |  |  |  |  |
32 | Net Sales Proceeds(Assoc. Co.) |  |  |  |  |  |  |  |  |  |  |  |
33 | Net Sales Proceeds (Other) |  |  |  |  |  |  |  |  |  |  |  |
34 | Gains |  |  |  |  |  |  |  |  |  |  |  |
35 | Losses |  |  |  |  |  |  |  |  |  |  |  |
| Allowances Withheld (Acct 158.2) |  |  |  |  |  |  |  |  |  |  |  |
36 | Balance-Beginning of Year |  |  |  |  |  |  |  |  |  |  |  |
37 | Add: Withheld by EPA |  |  |  |  |  |  |  |  |  |  |  |
38 | Deduct: Returned by EPA |  |  |  |  |  |  |  |  |  |  |  |
39 | Cost of Sales |  |  |  |  |  |  |  |  |  |  |  |
40 | Balance-End of Year |  |  |  |  |  |  |  |  |  |  |  |
41 |  |  |  |  |  |  |  |  |  |  |  |  |
42 | Sales |  |  |  |  |  |  |  |  |  |  |  |
43 | Net Sales Proceeds (Assoc. Co.) |  |  |  |  |  |  |  |  |  |  |  |
44 | Net Sales Proceeds (Other) |  |  |  |  |  |  |  |  |  |  |  |
45 | Gains |  |  |  |  |  |  |  |  |  |  |  |
46 | Losses |  |  |  |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
|  |  |  | WRITTEN OFF DURING YEAR |
Line No. | DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a) | ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b) | ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c) | ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d) | ExtraordinaryPropertyLossesWrittenOff Amount (e) | ExtraordinaryPropertyLosses Balance at End of Year (f)
1 |  |  |  |  |  |
2 |  |  |  |  |  |
3 |  |  |  |  |  |
4 |  |  |  |  |  |
5 |  |  |  |  |  |
6 |  |  |  |  |  |
7 |  |  |  |  |  |
8 |  |  |  |  |  |
9 |  |  |  |  |  |
10 |  |  |  |  |  |
11 |  |  |  |  |  |
12 |  |  |  |  |  |
13 |  |  |  |  |  |
14 |  |  |  |  |  |
15 |  |  |  |  |  |
16 |  |  |  |  |  |
17 |  |  |  |  |  |
18 |  |  |  |  |  |
19 |  |  |  |  |  |
20 |  |  |  |  |  |
21 |  |  |  |  |  |
22 |  |  |  |  |  |
23 |  |  |  |  |  |
24 |  |  |  |  |  |
25 |  |  |  |  |  |
26 |  |  |  |  |  |
27 |  |  |  |  |  |
28 |  |  |  |  |  |
20 | TOTAL |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
|  |  |  | WRITTEN OFF DURING YEAR |
Line No. | DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a) | UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b) | UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c) | UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d) | UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e) | UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21 |  |  |  |  |  |
22 |  |  |  |  |  |
23 |  |  |  |  |  |
24 |  |  |  |  |  |
25 |  |  |  |  |  |
26 |  |  |  |  |  |
27 |  |  |  |  |  |
28 |  |  |  |  |  |
29 |  |  |  |  |  |
30 |  |  |  |  |  |
31 |  |  |  |  |  |
32 |  |  |  |  |  |
33 |  |  |  |  |  |
34 |  |  |  |  |  |
35 |  |  |  |  |  |
36 |  |  |  |  |  |
37 |  |  |  |  |  |
38 |  |  |  |  |  |
39 |  |  |  |  |  |
40 |  |  |  |  |  |
41 |  |  |  |  |  |
42 |  |  |  |  |  |
43 |  |  |  |  |  |
44 |  |  |  |  |  |
45 |  |  |  |  |  |
46 |  |  |  |  |  |
47 |  |  |  |  |  |
48 |  |  |  |  |  |
49 | TOTAL |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No. | DescriptionOfStudyPerformed Description (a) | StudyCostsIncurred Costs Incurred During Period (b) | StudyCostsAccountCharged Account Charged (c) | StudyCostsReimbursements Reimbursements Received During the Period (d) | StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1 | Transmission Studies |  |  |  |
2 | (a) None |  |  |  |
20 | Total |  |  |  |
21 | Generation Studies |  |  |  |
22 | (b) None |  |  |  |
39 | Total |  |  |  |
40 | Grand Total |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfStudyPerformed
Southern Company Services receives up-front payments for studies and operating companies do not record any charges to these accounts. Costs are bore at system level. The only time an operating company would have anything to report on page 231 is when the charges exceed the amount collected and the customer does not reimburse Southern Company. Any study completed by an operating company and is under the OATT should be reported by that operating company on page 231.
(b) Concept: DescriptionOfStudyPerformed
Southern Company Services receives up-front payments for studies and operating companies do not record any charges to these accounts. Costs are bore at system level. The only time an operating company would have anything to report on page 231 is when the charges exceed the amount collected and the customer does not reimburse Southern Company. Any study completed by an operating company and is under the OATT should be reported by that operating company on page 231.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
|  |  |  | CREDITS |
Line No. | DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a) | OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b) | IncreaseDecreaseInOtherRegulatoryAssets Debits (c) | OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d) | OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e) | OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1 | (a) Vacation Pay Accrued | 107,812,868 | 14,548,326 | Various | 14,869,414 | 107,491,780
2 | (b) Deferred Income Taxes | 591,056,791 | 183,029,503 | 282,283 | 162,210,013 | 611,876,281
3 | (c) Retiree Benefit Plans | 906,509,220 | 210,905,248 | 228,407.3 | 54,955,599 | 1,062,458,869
4 | (d) Generating Plant Outage Costs | 29,724,187 | 49,437,011 | 407.3 | 46,512,195 | 32,649,003
5 | (e) Asset Retirement Obligations | 4,819,333,060 | 350,202,268 | 254,411 | 682,183,864 | 4,487,351,464
6 | (f) Gas and Electric Hedges | 66,691,260 | 196,551,087 | Various | 131,142,509 | 132,099,838
7 | (g) Storm Damage | 25,205,602 | 67,299,241 | 182.3,924 | 38,296,949 | 54,207,894
8 | (h) COVID-19 Costs |  | 25,205,602 | 407.3 | 8,401,868 | 16,803,734
9 | (i) Environmental Remediation | 25,067,587 | 138,724 | 924 | 5,052,418 | 20,153,893
10 | (j) Deferred Plant Retirement Costs | 970,825,246 |  | 407.3 | 124,245,097 | 846,580,149
11 | (k) Revenue Erosion | 1,268,628 | 1,517,411 | 442 | 1,457,798 | 1,328,241
12 | (l) Customer Data Usage | 325,759 | 87,816 | 905 | 262,013 | 151,562
13 | (m) Software & Cloud Computing | 58,956,357 | 34,627,546 | 923 | 9,781,703 | 83,802,200
14 | (n) Energy Efficiency Improvements | 33,017 |  | 908 | 5,131 | 27,886
15 | (o) Nuclear Decommissioning | 7,565,252 | 16,141,392 | 407.3 | 3,152,189 | 20,554,455
16 | (p) Deferred Plant Depreciation |  | 13,655,312 |  |  | 13,655,312
17 | (q) Nuclear Financing |  | 126,832,363 |  |  | 126,832,363
44 | TOTAL | 7,610,374,834 | 1,290,178,850 |  | 1,282,528,760 | 7,618,024,924

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Earned vacation pay is deferred and recognized only when paid as ordered by the Georgia Public Service Commission (PSC) in Docket No. 3270.
(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Plant Vogtle Units 3 and 4 Prudency Stipulation in Docket No. 29849, the unprotected deficient accumulated deferred income taxes associated with the remeasurement of deferred income taxes on the construction work in progress for Plant Vogtle Units 3 and 4 as a result of the Tax Cuts and Jobs Act will be recovered over a period of 10 years starting the month after Plant Vogtle Unit 4 achieves commercial operation. The remaining deferred income taxes are being amortized over the related remaining property lives in accordance with IRS normalization principles which may range up to 56 years.
|  | Beginning Balance |  | Amortized to 411.1 |  | Net DR/CR Adj |  | Ending Balance
Deferred Income Taxes |  | $ | 445,921,833 |  |  | $ | — |  |  | $ | 20,476,381 |  |  | $ | 466,398,214 |
Unprotected DADIT NCCR |  | $ | 145,134,958 |  |  | $ | — |  |  | $ | 343,109 |  |  | $ | 145,478,067 |
(c) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Retiree benefit plans are recovered through current rates over the average remaining service period as ordered by the Georgia PSC in Docket No. 4565, which may range up to 13 years.
(d) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Nuclear outage costs are deferred and amortized over the respective unit’s operating cycle as ordered by the Georgia PSC in Docket No. 4007.
(e) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Coal Combustion Residuals (CCR) AROs are recovered through the Environmental Compliance Cost Recovery tariff, with approximately $160 million recovered in 2023, and approximately $100 million and $325 million expected to be recovered in 2024 and 2025, respectively, with the recovery amount for future years updated through compliance filings. Approximately $17 million annually will be recovered for non-CCR AROs through traditional base tariffs. Other cost of removal obligations and non-CCR AROs are recovered over the related property lives, which may range up to 56 years.
(f) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Realized and unrealized losses arising from marked to market gas and electric hedges are deferred and recovered when settled as ordered by the Georgia PSC in Docket No. 16134. The Company's natural gas hedging program uses an array of derivative instruments within a 36-month time horizon, as ordered by the Georgia PSC in Docket No. 43011.
(g) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Effective January 1, 2023, the Company is accruing $31 million annually through December 31, 2025, as ordered by the Georgia PSC in Docket No. 44280, to cover the operations and maintenance costs of damages from major storms to its transmission and distribution facilities, which are recoverable through base rates. During the second quarter 2022, the Company’s regulatory asset for storm damage was eliminated and storm damages were reserved in FERC account 228.1. Significant storm damage costs incurred during the third quarter 2023 resulted in the Company’s storm damage reserves in FERC account 228.1 to be eliminated and a regulatory asset for storm damage was re-established. Storm Damage previously included deferred incremental costs related to COVID-19. See footnote (h) for additional information.
(h) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC order in Docket No. 42516, the Company deferred incremental bad debt and other incremental costs in certain identified cost categories that were incurred as result of the COVID-19 pandemic. At December 31, 2022, the incremental costs deferred totaled approximately $25 million. Effective January 1, 2023, the Company is amortizing these costs over a three-year period ending December 31, 2025, as ordered by the Georgia PSC in Docket No. 44280. COVID-19 costs were previously included in Storm Damage; see footnote (g) for additional information.
(i) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Effective January 1, 2023, the Company is accruing $5 million annually through December 31, 2025, as ordered by the Georgia PSC in Docket No. 44280, to cover the costs of environmental remediation.
(j) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC orders in Docket Nos. 34218, 36498, 42310 and 44160, deferred plant retirement costs, including remaining net book values and unusable materials and supplies inventories, are classified as a regulatory asset. The remaining net book values of Plant Branch Units 3 and 4 and Plant Hammond Units 1-4 are being amortized over a period equal to the units' remaining useful lives as approved by the Georgia PSC in Docket Nos. 31958 and 36989, respectively. Effective January 1, 2023, the remaining net book value of Plants Wansley Units 1 and 2 is being amortized over a period equal to the units' remaining useful lives as approved by the Georgia PSC in Docket No. 42516 and the remaining net book value of Plant Wansley CT Unit 5A is being amortized over a three-year period ending December 31, 2025, as ordered by the Georgia PSC in Docket No. 44280. The decision on the timing of the recovery of the unusable materials and supplies inventories will be deferred until a future base rate case.
(k) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC order in Docket No. 44280, any revenue erosion resulting from the conversion of additional customers to a specific time-of-use rate will be deferred and recovered from customers in 2023 through 2025 through the annual compliance filings.
(l) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC order in Docket No. 44280, costs associated with investigation and implementation of providing hourly usage information to all metered customers is being recovered over a three-year period ending December 31, 2025.
(m) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Effective January 1, 2023, certain implementation costs related to software and cloud computing projects incurred through 2022 were deferred and are being amortized over a five-year period ending December 31, 2027, in accordance with the Georgia PSC order in Docket No. 44280. The recovery of deferred costs incurred since 2022 will be determined by the Georgia PSC in the next base rate case.
(n) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC order in Docket Nos. 42310 and 42311, the costs of energy efficient upgrades, prepaid by the Company, for participating customers associated with the Income Qualified Tariff Based Energy Efficiency Pilot, or RISE pilot, are deferred and recovered from those customers over the life of the installed equipment not to exceed ten years.
(o) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Nuclear Regulatory Commission requirement to satisfy funding assurance for nuclear decommissioning, the Company provided funding to the external nuclear decommissioning trust for Plant Vogtle Unit 3 of $7.6 million in 2022. In 2023, the Company funded $0.8 million, $7.6 million, and $7.8 million related to Plant Vogtle Units 1, 3, and 4, respectively. Effective August 1, 2023, the Company is amortizing $7.6 million annually until the next base rate case, as ordered by the Georgia PSC in Docket No. 43838, for the funding of future costs related to decommissioning Plant Vogtle Unit 3. As ordered by the Georgia PSC in Docket No. 29849, the Company will amortize $7.8 million annually starting the month after Plant Vogtle Unit 4 commercial operation until the next base rate case, for the funding of future costs related to decommissioning Plant Vogtle Unit 4. The recovery of the $0.8 million of funding for Plant Vogtle Unit 1 will be determined by the Georgia PSC in the next base rate case.
(p) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Georgia PSC order in Docket No. 44280 to recover the net book values of Plants Bowen and Scherer through 2034, $40 million and $70 million of the depreciation for Plants Bowen and Scherer, respectively, are being deferred annually to a regulatory asset over the units' remaining useful lives through 2030 and 2028, respectively. The regulatory asset will be amortized beginning at the end of their useful lives through December 31, 2034. In accordance with the Plant Vogtle Unit 3 Base Rate Filing Order in Docket No. 43838, depreciation on Vogtle Unit 3 and common facilities capital and construction costs above $2.1 billion is being deferred to a regulatory asset until Vogtle Unit 4 achieves commercial operation. In accordance with the Vogtle Units 3 and 4 Prudency Stipulation in Docket No. 29849, the Company will amortize these costs over a period of 10 years starting the month after Plant Vogtle Unit 4 achieves commercial operation.
(q) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
In accordance with the Plant Vogtle Unit 3 Base Rate Filing Order in Docket No. 43838, financing costs on Plant Vogtle Unit 3 and common facilities capital and construction costs above $2.1 billion and excluded from the Nuclear Construction Cost Recovery Tariff are being deferred to a regulatory asset until Plant Vogtle Unit 4 achieves commercial operation. In accordance with the Plant Vogtle Units 3 and 4 Prudency Stipulation in Docket No. 29849, the Company will amortize these financing costs over a period of 10 years starting the month after Plant Vogtle Unit 4 achieves commercial operation.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
|  |  |  | CREDITS |
Line No. | Description of Miscellaneous Deferred Debits (a) | Balance at Beginning of Year (b) | Debits (c) | Credits Account Charged (d) | Credits Amount (e) | Balance at End of Year (f)
1 | Jobs in Progress - Cost | 3,466,770 | 29,390,346 | 143 | 19,252,071 | 13,605,045
2 | Joint Owner Other Deferred Billings | 5,523,458 | 10,334,818 | 902-926, 143 | 14,176,416 | 1,681,860
3 | Funding Collateral | 509,356 |  |  |  | 509,356
4 | Progress Payments | 42,579,916 | 113,675,227 | 107, 120.4, 154 | 84,590,219 | 71,664,924
5 | Non Current Fuel Cost Recovery | 2,056,093,569 | 2,520,979,653 | 440, 442, 444, 446 | 3,366,230,790 | 1,210,842,432
6 | (a) Cash Surrender Value Insurance (a) | 6,773,500 | 273,735 | 426.2 | 27,807 | 7,019,428
7 | Disputed Payments |  | 2,877,303 | 181 | 1,655,388 | 1,221,915
8 | Deferred Capitalized Interest on Nuclear Fuel During Construction | 39,437,917 | 4,316,855 | 432 | 5,548,067 | 38,206,705
9 | Miscellaneous Deferred Debits | 1,669,627 | 482,253 | Various | 1,525,600 | 626,280
10 | Other Post-Retirement Benefits and Pension-Associated Co | 185,186,581 | 30,161,840 | 234 |  | 215,348,421
11 | GPC Vogtle 3&4 Construction Payments | 18,770,002 | 359,389,349 | 107, 143 | 378,159,351 |
12 | (b) Credit Line Fees (b) | 4,032,782 | 2,747,456 | 431 | 1,466,403 | 5,313,835
13 | (c) Transmission Solar Interconnection (c) | 9,543,032 |  | 555 | 374,476 | 9,168,556
14 | Pooled Equipment Inventory Operating Fund Deposit | 65,196 |  |  |  | 65,196
15 | Mobile Device Billing | 4,149 |  | 146, 921 | 4,149 |
16 | (d) Sales Commissions (d) | 5,081,520 | 23,820,793 | 416, 912 | 24,021,578 | 4,880,735
17 |  |  |  | — |  |
47 | Miscellaneous Work in Progress |  |  |  |  |
48 | Deferred Regulatory Comm. Expenses (See pages 350 - 351) |  |  |  |  |
49 | TOTAL | 2,378,737,375 |  |  |  | 1,580,154,688

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfMiscellaneousDeferredDebits
Cash Surrender Value Insurance is amortized over a 12-month period.
(b) Concept: DescriptionOfMiscellaneousDeferredDebits
Credit line fees are amortized over the term of the related credit facility.
(c) Concept: DescriptionOfMiscellaneousDeferredDebits
Transmission Solar Interconnection reimbursements are being amortized over 20 or 30 years depending on the terms of the purchase power agreement starting in April 2017.
(d) Concept: DescriptionOfMiscellaneousDeferredDebits
Sales commissions are amortized over the term of the sales contracts which range from 2 to 3 years.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No. | DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a) | AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b) | AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1 | Electric |  |
2 |  | 1,375,977,052 | 1,347,309,257
7 | Other |  |
8 | TOTAL Electric (Enter Total of lines 2 thru 7) | 1,375,977,052 | 1,347,309,257
9 | Gas |  |
15 | Other |  |
16 | TOTAL Gas (Enter Total of lines 10 thru 15) |  |
17.1 | Other (Specify) | 119,499,441 | 156,781,694
17 | Other (Specify) |  |
18 | TOTAL (Acct 190) (Total of lines 8, 16 and 17) | (a) 1,495,476,493 | 1,504,090,951

Notes

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes
ACCUMULATED DEFERRED INCOME TAXES (ACCOUNT 190) | BALANCE AT BEG OF YEAR |  | BALANCE AT END OF YEAR
Accrual for Uncollectibles | $ | 645,749 |  |  | $ | 1,018,960 |
Accumulated Rate Refund Georgia Public Service Commission | 30,824,146 |  | 12.00 |
Affirmative Adjustments* | 8,478,950 |  | 8,478,950.00 |
Capacity Buybacks* | 7,630 |  | — |
Capitalized Purchase Power Agreement Southern Power Co | 8,472,722 |  | 8,878,525.00 |
Deferred Revenues - Electric | 54,237 |  | 981,932.00 |
Demand Side Management Recovery | 9,580,081 |  | 11,673,980.00 |
FAS 133 Mark to Market* | 7,763,311 |  | 7,776,485.00 |
Health Reimbursement Accrual | 587,397 |  | 598,744.00 |
Income Taxes Deferred - Electric | 243,576,200 |  | 252,848,015.00 |
Protected Gross Up EADIT | 552,719,580 |  | 530,655,047.00 |
Income Taxes Deferred - CWIP Electric | (18,292,275) |  | (8,376,711.00) |
Income Taxes Deferred - Non Electric* | 3,070,827 |  | (19,793,690.00) |
Income Taxes Deferred - CWIP Non Electric* | (39,575,884) |  | (16,158,001.00) |
Injuries & Damages Reserve | 3,862,585 |  | 696,625.00 |
Nuclear Construction Cost Recovery Over/Under Recovery | - |  | — |
Other Comprehensive Income - Hedge Settlement | 4,064,883 |  | 3,038,900.00 |
Other Basis Differences | 74,181,501 |  | 77,408,551.00 |
Accrued Liabilities - Electric | 110,588,151 |  | 109,516,969.00 |
Accrued Liabilities - Non Electric* | 15,461,181 |  | 16,445,346.00 |
Storm Damage | 22,214,683 |  | — |
Tax Credit Carry Forward - Electric | 346,558,564 |  | 363,710,569.00 |
Tax Credit Carry Forward - Non Electric* | 124,293,426 |  | 160,032,604.00 |
Unbilled Fuel Revenues | 23,051,473 |  | 31,714,873.00 |
Unprotected Gross Up Deficient EADIT NCCR | (36,712,625) |  | (37,055,734.00) |
| --------------------- |  | ---------------------
Total | $ | 1,495,476,493 |  |  | $ | 1,504,090,951 |
| --------------------- |  | ---------------------
*Other Income and Deductions |  |  |
Classification of Totals: |  |  |
Federal Income Tax | $ | 882,849,107 |  |  | $ | 828,576,722 |
State Income Tax | $ | 612,627,386 |  |  | $ | 675,514,229 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No. | Class and Series of Stock and Name of Stock Series (a) | Number of Shares Authorized by Charter (b) | Par or Stated Value per Share (c) | Call Price at End of Year (d) | Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e) | Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f) | Held by Respondent As Reacquired Stock (Acct 217) Shares (g) | Held by Respondent As Reacquired Stock (Acct 217) Cost (h) | Held by Respondent In Sinking and Other Funds Shares (i) | Held by Respondent In Sinking and Other Funds Amount (j)
1 | Common Stock (Account 201) |  |  |  |  |  |  |  |  |
2 | Common Stock (No Par) | 20,000,000 |  |  | 9,261,500 | 398,473,175 |  |  |  |
6 | Total | 20,000,000 |  |  | 9,261,500 | 398,473,175 |  |  |  |
7 | Preferred Stock (Account 204) |  |  |  |  |  |  |  |  |
8 | Cumulative Preferred, Par Value $100 Per Share | 5,000,000 | 100.00 |  |  |  |  |  |  |
9 | Non-Cumulative, Par Value $25 Per Share | 50,000,000 | 25.00 |  |  |  |  |  |  |
10 | Non-Cumulative, Par Value $100 Per Share | 15,000,000 | 100.00 |  |  |  |  |  |  |
20 | Total | 70,000,000 |  |  |  |  |  |  |  |
1 | Capital Stock (Accounts 201 and 204) - Data Conversion |  |  |  |  |  |  |  |  |
2 |  |  |  |  |  |  |  |  |  |
3 |  |  |  |  |  |  |  |  |  |
4 |  |  |  |  |  |  |  |  |  |
5 | Total |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 2024-04-01 | Year/Period of Report End of: 2023 / Q4

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No. | Item (a) | Amount (b)
1 | DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208) |
2 | DonationsReceivedFromStockholders Beginning Balance Amount |
3.1 | IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders |
4 | DonationsReceivedFromStockholders Ending Balance Amount |
5 | ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209) |
6 | ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount |
7.1 | IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock |
8 | ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount |
9 | GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) |
10 | GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount |
11.1 | IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock |
12 | GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount |
13 | MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211) |
14 | MiscellaneousPaidInCapital Beginning Balance Amount | 15,616,448,441
15.1 | IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital |
15.2 | IncreasesDecreasesDueToMiscellaneousPaidInCapital Contributions to capital by parent company | 2,290,884,036
15.3 | IncreasesDecreasesDueToMiscellaneousPaidInCapital Miscellaneous contributions to capital | 7,143,244
16 | MiscellaneousPaidInCapital Ending Balance Amount | 17,914,475,721
17 | OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital |
18 | OtherPaidInCapitalDetail Beginning Balance Amount |
19.1 | IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital |
20 | OtherPaidInCapitalDetail Ending Balance Amount |
40 | OtherPaidInCapital Total | 17,914,475,721

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No. | NameOfClassAndSeriesOfStock Class and Series of Stock (a) | CapitalStockExpense Balance at End of Year (b)
1 |  |
2 |  |
3 |  |
4 |  |
5 |  |
6 |  |
7 |  |
8 |  |
9 |  |
10 |  |
11 |  |
12 |  |
13 |  |
14 |  |
15 |  |
16 |  |
17 |  |
18 |  |
19 |  |
20 |  |
21 |  |
22 | TOTAL |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No. | ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a) | RelatedAccountNumber Related Account Number (b) | Principal Amount of Debt Issued (c) | LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d) | LongTermDebtIssuanceExpenses Total Expense (e) | LongTermDebtPremium Total Premium (f) | LongTermDebtDiscount Total Discount (g) | NominalDateOfIssue Nominal Date of Issue (h) | DateOfMaturity Date of Maturity (i) | AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j) | AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k) | Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l) | Interest for Year Amount (m)
1 | Bonds (Account 221) |  |  |  |  |  |  |  |  |  |  |  |
2 | Bartow 2nd Series 2009 | — | 100,000,000 |  |  |  |  |  |  |  |  | 100,000,000 |
3 | Subtotal |  | 100,000,000 |  |  |  |  |  |  |  |  | 100,000,000 |
4 | Reacquired Bonds (Account 222) |  |  |  |  |  |  |  |  |  |  |  |
5 | Bartow 2nd Series 2009 | — | 100,000,000 |  |  |  |  |  |  |  |  | 100,000,000 |
6 | Subtotal |  | 100,000,000 |  |  |  |  |  |  |  |  | 100,000,000 |
7 | Advances from Associated Companies (Account 223) |  |  |  |  |  |  |  |  |  |  |  |
8 |  |  |  |  |  |  |  |  |  |  |  |  |
9 |  |  |  |  |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |  |  |  |  |
11 | Subtotal |  |  |  |  |  |  |  |  |  |  |  |
12 | Other Long Term Debt (Account 224) |  |  |  |  |  |  |  |  |  |  |  |
13 | Series N - 5.750% | — | (b) 100,000,000 |  |  |  |  | 04/15/2003 | 04/15/2023 | 04/01/2003 | 04/15/2023 |  | 1,677,082
14 | Series 2007 A - 5.65% | — | 250,000,000 |  | 1,780,008 |  | 856,478 | 03/13/2007 | 03/01/2037 | 04/01/2007 | 03/01/2037 | 161,382,000 | 9,118,083
15 | Series 2007 D - 6.375% | — | 300,000,000 |  |  |  |  | 07/17/2007 | 07/15/2047 | 07/01/2007 | 07/15/2047 |  | (e) 184,976
16 | Series 2009A - 5.95% | — | 500,000,000 |  | 2,679,965 |  | 1,020,706 | 02/10/2009 | 02/01/2039 | 02/01/2009 | 02/01/2039 | 173,807,000 | 10,341,516
17 | Series 2010B - 5.4% | — | 600,000,000 |  | 3,385,341 |  | 2,335,496 | 06/03/2010 | 06/01/2040 | 06/01/2010 | 06/01/2040 | 264,898,000 | 14,304,492
18 | Series 2010C - 4.75% | — | 500,000,000 |  | 4,533,506 |  | 4,820,000 | 08/31/2010 | 09/01/2040 | 08/01/2010 | 09/01/2040 | 500,000,000 | 23,750,000
19 | Series 2012A - 4.30% | — | 1,100,000,000 |  | 10,792,848 | 4,228,165 | 383,702 | 03/06/2012 | 03/15/2042 | 03/01/2012 | 03/15/2042 | 1,100,000,000 | 47,300,000
20 | Series 2013A - 4.3% | — | 400,000,000 |  | 3,884,160 |  | 2,604,020 | 03/15/2013 | 03/15/2043 | 03/01/2013 | 03/15/2043 | 400,000,000 | 17,200,000
21 | Series 2016A - 3.25% | — | 325,000,000 |  | 2,337,915 |  | 1,222,000 | 03/08/2016 | 04/01/2026 | 03/01/2016 | 04/01/2026 | 325,000,000 | 10,562,500
22 | Series 2017B - 3.25% | — | 400,000,000 |  | 2,876,271 |  | 452,000 | 03/03/2017 | 03/30/2027 | 03/01/2017 | 03/30/2027 | 400,000,000 | 12,982,879
23 | Series 2019A - 2.20% | — | 400,000,000 |  | 2,758,160 |  | 320,000 | 09/10/2019 | 09/15/2024 | 09/01/2019 | 09/15/2024 | 400,000,000 | 8,800,000
24 | Series 2019B - 2.65% | — | 650,000,000 |  | 4,769,103 |  | 4,882,500 | 09/10/2019 | 09/15/2029 | 09/01/2019 | 09/15/2029 | 650,000,000 | 21,118,872
25 | Series 2020A - 2.10% | — | 700,000,000 |  |  |  |  | 01/10/2020 | 07/30/2023 | 01/01/2020 | 07/30/2023 |  | 8,575,000
26 | Series 2020B - 3.70% | — | 500,000,000 |  | 4,707,331 |  | 1,630,000 | 01/10/2020 | 01/30/2050 | 01/01/2020 | 01/30/2050 | 500,000,000 | 19,868,269
27 | Series 2021A - 3.25% | — | 750,000,000 |  | 7,142,232 |  | 727,500 | 02/26/2021 | 03/15/2051 | 02/26/2021 | 03/15/2051 | 750,000,000 | 24,375,000
28 | Series 2022A - 4.70% | — | 700,000,000 |  | 5,057,712 |  | 2,226,000 | 05/04/2022 | 05/15/2032 | 05/04/2022 | 05/15/2032 | 700,000,000 | 31,104,696
29 | Series 2022B - 5.125% | — | 800,000,000 |  | 7,426,647 |  | 5,840,000 | 05/04/2022 | 05/15/2052 | 05/04/2022 | 05/15/2052 | 800,000,000 | 40,558,334
30 | Series 2023A - 4.65% |  | 750,000,000 |  | 5,085,398 |  | 945,000 | 05/04/2023 | 05/16/2028 | 05/04/2023 | 05/16/2028 | 750,000,000 | 22,766,555
31 | Series 2023B - 4.95% |  | 1,000,000,000 |  | 7,204,869 |  | 1,740,000 | 05/04/2023 | 05/17/2033 | 05/04/2023 | 05/17/2033 | 1,000,000,000 | 32,851,674
32 | Series 2023C - Variable |  | 700,000,000 |  | 1,943,820 |  |  | 11/08/2023 | 05/08/2025 | 11/08/2023 | 05/08/2025 | 700,000,000 | 6,089,170
33 | Heard 1st Series 1996 - Variable | — | 3,800,000 |  | 281,716 |  |  | 09/01/1996 | 09/01/2026 | 09/01/1996 | 09/01/2026 | 3,800,000 | 131,535
34 | Floyd 1st Series 1996 - Variable | — | 10,080,000 |  | 234,522 |  |  | 09/01/1996 | 09/01/2026 | 09/01/1996 | 09/01/2026 | 10,080,000 | 347,832
35 | Burke 1st Series 1996 - Variable | — | 46,000,000 |  | 1,346,718 |  |  | 09/01/1996 | 10/01/2032 | 09/01/1996 | 10/01/2032 | 46,000,000 | 1,699,452
36 | Monroe 1st Series 1997 - Variable | — | 19,600,000 |  | 719,734 |  |  | 04/01/1997 | 04/01/2032 | 04/01/1997 | 04/01/2032 | 19,600,000 | 676,340
37 | Appling 1st Series 1997 - Variable | — | 18,500,000 |  | 863,498 |  |  | 09/01/1997 | 09/01/2029 | 09/01/1997 | 09/01/2029 | 18,500,000 | 638,382
38 | Heard 1st Series 1997 - Variable | — | 33,700,000 |  | 800,281 |  |  | 09/01/1997 | 09/01/2029 | 09/01/1997 | 09/01/2029 | 33,700,000 | 1,153,334
39 | Bartow 1st Series 1997 - 1.80% | — | 38,000,000 |  | 1,827,936 |  |  | 09/01/1997 | 09/01/2029 | 09/01/1997 | 09/01/2029 | 38,000,000 | 684,000
40 | Burke 2nd Series 1994 - 2.25% | — | 10,000,000 |  | 275,986 |  |  | 01/01/1994 | 10/01/2032 | 01/01/1994 | 10/01/2032 | 10,000,000 | 318,000
41 | Burke 4th Series 1994 - 2.25% | — | 55,000,000 |  | 919,195 |  |  | 01/01/1994 | 10/01/2032 | 01/01/1994 | 10/01/2032 | 55,000,000 | 1,749,000
42 | Burke 5th Series 1994 - 2.15% | — | 55,000,000 |  | 1,599,536 |  |  | 01/01/1994 | 10/01/2032 | 01/01/1994 | 10/01/2032 | 55,000,000 | 1,182,500
43 | Burke 9th Series 1994 - 2.25% | — | 20,000,000 |  | 425,804 |  |  | 01/01/1994 | 10/01/2032 | 01/01/1994 | 10/01/2032 | 20,000,000 | 636,000
44 | Monroe 1st Series 1995 - 2.25% | — | 45,000,000 |  | 1,543,239 |  |  | 07/01/1995 | 07/01/2025 | 07/01/1995 | 07/01/2025 | 45,000,000 | 1,012,500
45 | Burke 4th Series 1995 - 2.25% | — | 30,000,000 |  | 546,739 |  |  | 09/01/1995 | 10/01/2032 | 09/01/1995 | 10/01/2032 | 30,000,000 | 954,000
46 | Burke 5th Series 1995 - 2.20% | — | 27,000,000 |  | 1,398,809 |  |  | 09/01/1995 | 09/01/2032 | 09/01/1995 | 09/01/2032 | 27,000,000 | 594,000
47 | Coweta 1st Series 2006 - Variable | — | 10,125,000 |  | 371,668 |  |  | 06/28/2006 | 06/01/2032 | 06/28/2006 | 06/01/2032 | 10,125,000 | 349,385
48 | Effingham 1st Series 2003 - Variable | — | 13,870,000 |  | 435,117 |  |  | 02/19/2003 | 02/01/2038 | 02/19/2003 | 02/01/2038 | 13,870,000 | 480,103
49 | Monroe 2nd Series 2006 - Variable | — | (c) 28,065,000 |  | 1,673,206 |  |  | 12/13/2006 | 12/01/2041 | 12/13/2006 | 12/01/2041 | 28,065,000 | 1,030,745
50 | Heard 1st Series 2007 - Variable | — | 17,800,000 |  | 403,140 |  |  | 12/06/2007 | 12/01/2037 | 12/06/2007 | 12/01/2037 | 17,800,000 | 613,846
51 | Burke 1st Series 2008 - Variable | — | 68,535,000 |  | 1,902,711 |  |  | 11/25/2008 | 11/01/2048 | 11/25/2008 | 11/01/2048 | 68,535,000 | 2,364,946
52 | Burke 2nd Series 2008 - 2.93% | — | 65,000,000 |  | 1,570,472 |  |  | 11/25/2008 | 11/01/2048 | 11/25/2008 | 11/01/2048 | 65,000,000 | 1,901,250
53 | Monroe 1st Series 2008 - Variable | — | 83,515,000 |  | 1,509,886 |  |  | 11/25/2008 | 11/01/2048 | 11/25/2008 | 11/01/2048 | 83,515,000 | 2,881,862
54 | Monroe 1st Series 2009 - 1.00% | — | 40,000,000 |  | 1,428,520 |  |  | 07/14/2009 | 07/01/2049 | 07/14/2009 | 07/01/2049 | 40,000,000 | 400,000
55 | Burke 1st Series 2009 - Variable | — | 114,310,000 |  | 1,573,880 |  |  | 07/14/2009 | 07/01/2049 | 07/14/2009 | 07/01/2049 | 114,310,000 | 3,841,067
56 | Monroe 2nd Series 2009 - Variable | — | 89,200,000 |  | 1,738,909 |  |  | 09/17/2009 | 10/01/2048 | 09/17/2009 | 10/01/2048 | 89,200,000 | 3,351,961
57 | Bartow 1st Series 2009 - 2.75% | — | 173,000,000 |  | 3,580,633 |  |  | 09/17/2009 | 12/01/2032 | 09/17/2009 | 12/01/2032 | 173,000,000 | 6,406,767
58 | Appling First Series 2011 - Variable | — | 67,000,000 |  | 1,127,321 |  |  | 09/01/2011 | 09/01/2041 | 09/01/2011 | 09/01/2041 | 67,000,000 | 2,311,977
59 | Monroe 1st Series 2012 - Variable | — | 48,720,000 |  | 1,705,983 |  |  | 05/01/2012 | 06/01/2042 | 05/01/2012 | 06/01/2042 | 48,720,000 | 1,798,994
60 | Burke 1st Series 2012 - 2.88% | — | 85,000,000 |  | 2,617,273 |  |  | 06/01/2012 | 12/01/2049 | 06/01/2012 | 12/01/2049 | 85,000,000 | 2,443,750
61 | Burke 2nd Series 2012 - 1.70% | — | 100,000,000 |  | 3,194,933 |  |  | 06/01/2012 | 12/01/2049 | 06/01/2012 | 12/01/2049 | 100,000,000 | 1,700,000
62 | Burke 3rd Series 2012 - Variable | — | 50,000,000 |  | 2,657,911 |  |  | 11/01/2012 | 11/01/2052 | 11/01/2012 | 11/01/2052 | 50,000,000 | 1,727,616
63 | Burke 1st Series 2013 - 2.93% | — | 104,600,000 |  | 6,446,122 |  |  | 11/08/2013 | 11/01/2053 | 11/01/2013 | 11/01/2053 | 104,600,000 | 3,059,550
64 | Monroe 1st Series 2013 - Variable | — | 17,500,000 |  | 1,603,424 |  |  | 03/21/2013 | 04/01/2043 | 03/21/2013 | 04/01/2043 | 17,500,000 | 642,724
65 | Bartow 1st Series 2013 - 2.88% | — | 71,735,000 |  | 1,291,583 |  |  | 08/23/2013 | 08/01/2043 | 08/23/2013 | 08/01/2043 | 71,735,000 | 2,062,381
66 | Burke 1st Series 2018 - Variable | — | 108,155,000 |  | 929,925 |  |  | 12/05/2018 | 11/01/2052 | 12/05/2018 | 11/01/2052 | 108,155,000 | 3,836,243
67 | Bartow 1st Series 2022 - Variable | — | 100,000,000 |  | 372,434 |  |  | 11/04/2022 | 11/01/2062 | 11/04/2022 | 11/01/2062 | 100,000,000 | 3,455,233
68 | Bartow 2nd Series 2022 - Variable | — | 100,000,000 |  | 182,696 |  |  | 11/04/2022 | 11/01/2062 | 11/04/2022 | 11/01/2062 | 100,000,000 | 3,426,822
69 | Series 2017A - 5.00% | — | 270,000,000 |  | 7,564,746 |  |  | 09/21/2017 | 10/01/2077 | 09/01/2017 | 10/01/2077 | 270,000,000 | 13,500,000
70 | (a) DOE Loan 3.860% - 2044 | — | 500,000,000 |  | (d) 65,433,621 |  |  | 02/20/2014 | 02/20/2044 | 02/20/2014 | 02/20/2044 | 466,640,000 | 18,177,896
71 | DOE Loan 3.488% - 2044 | — | 500,000,000 |  |  |  |  | 02/20/2014 | 02/20/2044 |  |  | 466,640,000 | 16,426,037
72 | DOE Loan 3.002% - 2044 | — | 200,000,000 |  |  |  |  | 12/11/2014 | 02/20/2044 |  |  | 186,656,000 | 5,654,927
73 | DOE Loan 3.283% - 2044 | — | 600,000,000 |  |  |  |  | 06/12/2015 | 02/20/2044 |  |  | 559,968,000 | 19,104,157
74 | DOE Loan 3.072% - 2044 | — | 400,000,000 |  |  |  |  | 12/09/2015 | 02/20/2044 |  |  | 373,312,000 | 13,213,689
75 | DOE Loan 2.571% - 2044 | — | 300,000,000 |  |  |  |  | 06/08/2016 | 02/20/2044 |  |  | 279,984,000 | 7,264,566
76 | DOE Loan 3.142% - 2044 | — | 125,000,000 |  |  |  |  | 12/08/2016 | 02/20/2044 |  |  | 116,660,000 | 3,699,155
77 | DOE Loan 3.213% - 2044 | — | 835,000,000 |  |  |  |  | 03/15/2019 | 02/20/2044 |  |  | 779,288,800 | 25,268,736
78 | DOE Loan 2.537% - 2044 | — | 2,409,117 |  |  |  |  | 12/20/2019 | 02/20/2044 |  |  | 2,248,381 | 57,566
79 | DOE Loan 2.537% - 2044 2 | — | 380,590,883 |  | 12,185,988 |  |  | 12/20/2019 | 02/20/2044 | 12/20/2019 | 02/20/2044 | 355,197,859 | 10,164,434
80 | DOE Loan 1.652% - 2044 | — | 519,000,000 |  |  |  |  | 06/05/2020 | 02/20/2044 |  |  | 484,372,320 | 8,075,394
81 | DOE Loan 1.737% - 2044 | — | 329,000,000 |  |  |  |  | 12/10/2020 | 02/20/2044 |  |  | 307,049,120 | 5,382,475
82 | DOE Loan 2.434% - 2044 | — | 371,000,000 |  |  |  |  | 06/24/2021 | 02/20/2044 |  |  | 346,246,880 | 8,505,127
83 | DOE Loan 2.178% - 2044 | — | 68,632,896 |  |  |  |  | 12/10/2021 | 02/20/2044 |  |  | 64,053,709 | 1,407,915
84 | Subtotal |  | 18,793,442,896 |  | 214,651,101 | 4,228,165 | 32,005,402 |  |  |  |  | 16,601,214,069 | 580,925,317
33 | TOTAL |  | 18,793,442,896 |  |  |  |  |  |  |  |  | 16,601,214,069 | 580,925,317

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: ClassAndSeriesOfObligationCouponRateDescription
In 2023, the following DOE Loan principal payments were made:
DOE Loan 3.860%, 2044 | $ | 8,340,000 |
DOE Loan 3.488%, 2044 | 8,340,000 |
DOE Loan 3.002%, 2044 | 3,336,000 |
DOE Loan 3.283%, 2044 | 10,008,000 |
DOE Loan 3.072%, 2044 | 6,672,000 |
DOE Loan 2.571%, 2044 | 5,004,000 |
DOE Loan 3.142%, 2044 | 2,085,000 |
DOE Loan 3.213%, 2044 | 13,927,800 |
DOE Loan 2.537%, 2044 | 40,184 |
DOE Loan 2.537%, 2044 | 6,348,256 |
DOE Loan 1.652% 2044 | 8,656,920 |
DOE Loan 1.737% 2044 | 5,487,720 |
DOE Loan 2.434% 2044 | 6,188,280 |
DOE Loan 2.178% 2044 | 1,144,797 |
| $ | 85,578,957 |
(b) Concept: OtherLongTermDebtPrincipalAmountIssued
In 2023, the following Senior Notes were issued: May 2023 - Series 2023A- 4.65% - $750,000,000 - due May 2028 May 2023 - Series 2023B- 4.95% - $1,000,000,000 - due May 2033 November 2023 - Series 2023C- Variable - $700,000,000 - due May 2025 In 2023, the following Senior Notes matured: April 2023 - Series N- 5.75% - $100,000,000 - due April 2023 July 2023 - Series 2020A- 2.10% - $700,000,000 - due July 2023
(c) Concept: OtherLongTermDebtPrincipalAmountIssued
The following PCBs were reoffered to the public in February 2023: Monroe 2nd Series 2006 $28,065,000 Monroe 2nd Series 2009 $89,200,000 Monroe 1st Series 2012 $48,720,000 Monroe 1st Series 2013 $17,500,000 Burke 1st Series 1996 $46,000,000
(d) Concept: OtherLongTermDebtIssuanceExpense
The $65,433,621 and $12,185,988 in issuance expenses on lines 70 and 79, respectively, are related to all DOE Loan draws.
(e) Concept: InterestExpenseOtherLongTermDebt
Amortization of gain on cash flow hedge on Series 2007D Senior Note, which was redeemed in July 2012, is being credited to FERC account 427 through June 2037.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No. | Particulars (Details) (a) | Amount (b)
1 | Net Income for the Year (Page 117) | 2,079,614,443
2 | Reconciling Items for the Year |
3 |  |
4 | Taxable Income Not Reported on Books |
5 | See Attachment 261.1 | (a) 207,079,864
9 | Deductions Recorded on Books Not Deducted for Return |
10 | See Attachment 261.1 | (b) 762,690,857
14 | Income Recorded on Books Not Included in Return |
15 | See Attachment 261.1 | (c) 180,563,326
19 | Deductions on Return Not Charged Against Book Income |
20 | See Attachment 261.1 | (d) 1,675,502,378
27 | Federal Tax Net Income | 1,193,319,460
28 | Show Computation of Tax: |
29 | Federal Income Tax @ 21% | 250,597,087
30 | Federal Tax Credits | 45,765,724
31 | Tax Reserve | 11,466
32 | Total Income Tax Payable | 204,842,829

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooks
TAXABLE INCOME NOT ON THE BOOKS
Financial Accounting Standards Board Statement No. 133 - Mark to Market | $ | 51,721 |
Demand Side Management Over/Under Recovery | 8,220,494 |
Unbilled Fuel Revenues | 34,011,870 |
Deferred Revenue & Expense | 1,749,376 |
Nuclear Construction Cost Recovery | 6,673,439 |
Fuel Clause Over/Under Recovery | 151,446,776 |
Prepaid Rental Income | 4,080,437 |
Other | 845,751 |
TOTAL | $ | 207,079,864 |
(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturn
EXPENSES RECORDED ON BOOKS NOT DEDUCTED ON TAX RETURN
Federal Income Tax | $ | 399,753,749 |
State Income Tax | 48,357,226 |
Administrative & General Accruals | 34,534,427 |
Capitalized Purchase Power Agreement Southern Power Company | 1,593,152 |
Deferred Interest on Nuclear Fuel V3&4 | 1,241,132 |
Premium on Reacquired Debt (Loss) | 15,723,311 |
Non Deductible Depreciation | 91,310,361 |
Municipal Gross Receipts Tax | 44,131,682 |
50% Meals & Entertainment Expense | 4,986,727 |
Environmental Remediation Reserve | 4,913,693 |
Bad Debt Reserve | 1,465,198 |
Severance Pay Plan | 11,430,780 |
Employee Parking Disallowance | 1,476,665 |
Regulatory Asset Wansley 1-2 | 26,250,198 |
Regulatory Asset COVID19 Costs | 8,401,867 |
Ad Valorem Equalization | 1,293,000 |
Expenditures Not Deductible Section 162/274 | 16,724,045 |
Regulatory Retired Units | 46,370,794 |
Other Deferred Costs | 2,732,850 |
TOTAL | $ | 762,690,857 |
(c) Concept: IncomeRecordedOnBooksNotIncludedInReturn
INCOME ON BOOKS NOT INCLUDED IN RETURN
Allowance for Funds Used During Construction - Equity | $ | 147,082,877 |
Amortization of Investment Tax Credit | 10,981,079 |
Customer Advances for Construction | 14,033,234 |
Equity in Earnings of Subs/Partnerships (SEGCO) | 6,141,773 |
Unbilled Revenues - Flat Bill Under Recovery | 1,048,118 |
Other | 1,276,245 |
TOTAL | $ | 180,563,326 |
(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncome
DEDUCTIONS NOT CHARGED AGAINST BOOK INCOME
Other Post Retirement Benefits | 64,546,421 |
Regulatory Asset Cloud Computing | 24,845,841 |
Deferred Compensation Board of Directors | 5,121,747 |
Other Post Employment Benefit FAS # 112 | 4,863,075 |
Regulatory Asset TOU MB REVENUE Erosion | 59,612 |
Regulatory Asset Bowen Deferral | 40,222,281 |
Regulatory Asset Scherer Deferral | 69,619,638 |
Regulatory Asset V3&4 Depreciation Deferral | 16,990,444 |
Regulatory Asset V3&4 Financing Costs | 13,655,312 |
Stock Based Compensation | 8,113,057 |
Storm Damage Reserve | 137,532,608 |
Retail Sharing | 121,013,266 |
Nuclear Outage | 2,924,815 |
Transmission Parity Accrual | 837,000 |
Vogtle Probable Loss | 116,316,721 |
Injuries and Damages Reserve | 12,429,326 |
Pension | 139,847,230 |
State Income Tax Payable | 37,436,888 |
Other | 8,332,481 |
Depreciation Related Timing Differences | 850,794,615 |
TOTAL | $ | 1,675,502,378 |
CONSOLIDATION AND ALLOCATION INFORMATION Members of Group and Tax Allocation (Note 1)
Alabama Power Company | $ | 240,860,714 |
Alabama Property Company | 876,750 |
Align | (224,542) |
Aladyn | — |
Georgia Power Company | 204,842,829 |
Piedmont-Forrest Corporation | 257,265 |
Mississippi Power Company | 48,829,996 |
Southern Company Gas | 61,869,817 |
Southern Electric Generating Company | 14,361,210 |
Southern Linc | 8,718,641 |
Southern Nuclear | 755,778 |
Southern | (212,085,861) |
So Holdings | (777,577) |
SPS Holdings | 519,819 |
So Power | (320,437,208) |
Eliminations | 6,032,206 |
Total Consolidation and Allocation Information | $ | 54,399,837 |
Note 1: Basis of Allocation: The consolidated federal income tax is allocated under Section 1552 (a) (1) of the Internal Revenue Code of 1986 as prescribed by Rule 45 (c) of the Securities and Exchange Commission’s regulations with certain modifications approved by the Securities and Exchange Commission.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
|  |  |  |  | BALANCE AT BEGINNING OF YEAR |  |  |  | BALANCE AT END OF YEAR | DISTRIBUTION OF TAXES CHARGED
Line No. | DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a) | TypeOfTax Type of Tax (b) | TaxJurisdiction State (c) | TaxYear Tax Year (d) | TaxesAccrued Taxes Accrued (Account 236) (e) | PrepaidTaxes Prepaid Taxes (Include in Account 165) (f) | TaxesCharged Taxes Charged During Year (g) | TaxesPaid Taxes Paid During Year (h) | TaxAdjustments Adjustments (i) | TaxesAccrued Taxes Accrued (Account 236) (j) | PrepaidTaxes Prepaid Taxes (Included in Account 165) (k) | TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l) | IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m) | AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n) | TaxesIncurredOther Other (o)
1 |  |  |  |  |  |  |  |  |  |  | 0 |  |  |  |
2 | Property Tax - 2021 & Prior | Property Tax | Georgia |  | 8,901,329 | 0 | 0 | 0 | 1,326,132 | 7,575,197 | 0 | 1,326,133 | 0 | 0 | 1,326,133
3 | Property Tax - 2022 | Property Tax | Georgia |  | 192,351,786 | 0 | 0 | 194,379,529 | 0 | 2,027,743 | 0 | 0 | 0 | 0 | 0
4 | Property Tax - 2023 | Property Tax | Georgia |  | 0 | 1,415,915 | 345,062,530 | 66,958,210 | 0 | 278,292,494 | 1,604,089 | 282,638,128 | 0 | 0 | 61,008,487
5 | Property Tax - 2021 & Prior | Property Tax | Alabama |  | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0
6 | Property Tax - 2022 | Property Tax | Alabama |  | 0 | 0 | 2,543,505 | 1,690,671 | 0 | 852,834 | 0 | 1,351,722 | 0 | 0 | 1,191,783
7 | Property Tax - 2021 & Prior | Property Tax | Mississippi |  | 141,927 |  | 0 | 143,606 | 0 | 1,679 | 0 | 0 | 0 | 0 | 0
8 | Property Tax - 2022 | Property Tax | Mississippi |  | 0 | 0 | 427,722 | 231,199 | 0 | 196,523 | 0 | 427,722 | 0 | 0 | 0
9 | Property Tax - 2021 & Prior | Property Tax | South Carolina |  | 576 | 0 | 0 | 610 | 0 | 34 | 0 | 0 | 0 | 0 | 0
10 | Property Tax - 2022 | Property Tax | South Carolina |  | 0 | 0 | 86,866 | 68,496 | 0 | 18,370 | 0 | 69,092 | 0 | 0 | 17,774
11 | Property Tax - 2021 & Prior | Property Tax | Tennessee |  | 18 | 0 | 0 | 0 | 0 | 18 | 0 | 0 | 0 | 0 | 0
12 | Property Tax - 2022 | Property Tax | Tennessee |  | 0 | 0 | 6 | 6 | 0 | 0 | 0 | 6 | 0 | 0 | 0
13 | Subtotal Property Tax |  |  |  | 201,395,636 | 1,415,915 | 348,120,629 | 263,472,327 | 1,326,132 | 284,905,980 | 1,604,089 | 283,160,537 | 0 | 0 | 63,544,177
14 | Federal Income Taxes 2022 & Prior | Income Tax |  |  | 15,047,302 | 0 | 6,094,550 | 31,576,540 | 22,934,470 | 310,682 | 0 | 17,648,944 |  | 0 | 11,554,394
15 | Federal Income Taxes 2023 | Income Tax |  |  |  | 0 | 210,937,379 | 196,041,729 | 40,762,065 | 313,530 | 25,552,885 | 224,846,709 |  | 0 | 13,909,330
16 | State Income Tax | Income Tax | Georgia |  | 7,801 | 11,979,474 | 37,436,888 | 41,926,268 | 0 | 37,541 | 16,498,594 | 55,563,409 |  | 0 | 18,126,521
17 | Subtotal Income Tax |  |  |  | 15,055,103 | 11,979,474 | 242,279,717 | 269,544,537 | 17,827,595 | 34,693 | 42,051,479 | 262,761,174 | 0 | 0 | 20,481,457
18 | Franchise Fees - 2022 | Franchise Tax | Georgia |  | 276,891,858 | 0 | 0 | 220,019,431 | 0 | 56,872,427 | 0 | 0 | 0 | 0 | 0
19 | Franchise Fees - 2023 | Franchise Tax | Georgia |  | 0 | 0 | 224,633,579 | 0 | 0 | 224,633,579 | 0 | 224,633,579 | 0 | 0 | 0
20 | Subtotal Franchise Tax |  |  |  | 276,891,858 | 0 | 224,633,579 | 220,019,431 | 0 | 281,506,006 | 0 | 224,633,579 | 0 | 0 | 0
21 | Net Worth | Other License And Fees Tax | Georgia |  | 0 | 0 | 10,000 | 10,000 | 0 | 0 | 0 | 10,000 |  | 0 | 0
22 | Business License | Other License And Fees Tax | Alabama |  | 0 | 0 | 925 | 925 | 0 | 0 | 0 | 925 |  | 0 | 0
23 | Business License | Other License And Fees Tax | Mississippi |  | 0 | 0 | 14,579 | 14,579 | 0 | 0 | 0 | 14,579 |  | 0 | 0
24 | Subtotal Other License And Fees Tax |  |  |  | 0 | 0 | 23,654 | 23,654 | 0 | 0 | 0 | 23,654 | 0 | 0 | 0
25 | FUTA | Payroll Tax | — |  | 0 | 0 | 319,715 | 319,715 | 0 | 0 | 0 | 319,715 | 0 | 0 | 0
26 | SUTA | Payroll Tax | Georgia |  | 0 | 0 | 226,717 | 226,717 | 0 | 0 | 0 | 244,753 | 0 | 0 | 18,036
27 | SUTA | Payroll Tax | Alabama |  | 0 | 0 | 1,674 | 1,674 | 0 | 0 | 0 | 1,674 | 0 | 0 | 0
28 | FICA | Payroll Tax | — |  | 14,225,411 | 0 | 0 | 1,244,047 | 0 | 15,469,458 | 0 | 30,933,033 | 0 | 0 | 30,933,033
29 | FICA-COVID 19 Federal | Payroll Tax | — |  |  |  | 0 | 0 | 0 |  | 0 | 0 | 0 | 0 | 0
30 | FICA-COVID 19 State | Payroll Tax | — |  | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0
31 | Subtotal Payroll Tax |  |  |  | 14,225,411 | 0 | 548,106 | 695,941 | 0 | 15,469,458 | 0 | 31,499,175 | 0 | 0 | 30,951,069
32 | Motor Vehicle Tag Fees | Other Taxes and Fees | — |  | 522,344 | 0 | 0 | 522,344 | 0 | 0 | 0 | 0 |  | 0 | 0
33 | Subtotal Other Taxes And Fees |  |  |  | 522,344 | 0 | 0 | 522,344 | 0 | 0 | 0 | 0 | 0 | 0 | 0
40 | TOTAL |  |  |  | 508,090,352 | 13,395,389 | 815,605,685 | 752,886,352 | 19,153,727 | 581,916,137 | 43,655,568 | 802,078,119 | 0 | 0 | 12,111,651

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
|  |  | Deferred for Year | Allocations to Current Year's Income |  |  |  |
Line No. | Account Subdivisions (a) | Balance at Beginning of Year (b) | Account No. (c) | Amount (d) | Account No. (e) | Amount (f) | Adjustments (g) | Balance at End of Year (h) | Average Period of Allocation to Income (i) | ADJUSTMENT EXPLANATION (j)
1 | Electric Utility |  |  |  |  |  |  |  |  |
2 | 3% |  |  |  |  |  |  |  |  |
3 | 4% | 276,122 |  |  | 411 | 27,916 |  | 248,206 | 56 |
4 | 7% |  |  |  |  |  |  |  |  |
5 | 10% | 123,114,474 |  |  | 411 | 8,022,201 |  | 115,092,273 | 55 |
6 | 30 | 195,442,411 |  |  | 411 | 2,930,962 | 17,827,595 | 210,339,044 | 33 |
8 | TOTAL Electric (Enter Total of lines 2 thru 7) | 318,833,007 |  |  |  | 10,981,079 | 17,827,595 | 325,679,523 |  |
9 | Other (List separately and show 3%, 4%, 7%, 10% and TOTAL) |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |  | `
47 | OTHER TOTAL |  |  |  |  |  |  |  |  |
48 | GRAND TOTAL | 318,833,007 |  |  |  |  |  | 325,679,523 |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
|  |  | DEBITS |  |
Line No. | Description and Other Deferred Credits (a) | Balance at Beginning of Year (b) | Contra Account (c) | Amount (d) | Credits (e) | Balance at End of Year (f)
1 | Workforce Reduction Programs | 136,763 | 234 | 5,802 |  | 130,961
2 | Deferred Compensation | 40,283,333 | 131, 426.5 | 11,461,208 | 6,614,266 | 35,436,391
3 | (a) Deferred Revenue (a) | 595,094 | 454 | 116,984 | 9,516 | 487,626
4 | (b) Advanced Contribution for Construction (b) | 134,462,601 | 107,121, 451 | 56,859,095 | 44,099,314 | 121,702,820
5 | Deferred Affiliate Taxes Payable | 223,323 | 234 | 150,621 |  | 72,702
6 | Long-Term Service Agreement | 35,323,869 | 131, 242 | 8,504,024 | 12,710,619 | 39,530,464
7 | Contract Retention | 8,113,800 | 143, 186, 101, 107 | 25,628,506 | 20,983,936 | 3,469,230
8 | (c) Prepaid Rent for Outdoor Lighting (c) | 6,385,992 | 451 | 42,841,958 | 44,429,822 | 7,973,856
9 | Renewable Generation Collateral | 21,512,494 | 131 | 4,656,075 | 1,013,769 | 17,870,188
10 | Vogtle 3&4 Construction | 15,513,199 | 242, 107 | 55,681,038 | 40,167,839 |
11 | Miscellaneous Deferred Credits | 602,174 | 131, 421 | 3,282,070 | 3,273,928 | 594,032
12 | Software Licensing | 1,500,000 | 242 | 1,500,000 |  |
13 | (d) Utility Services Contracts (d) | 1,888,610 | 242 | 2,116,116 | 345,882 | 118,376
14 | (e) Distribution Services (e) | 1,923,068 | 451 | 107,179 |  | 1,815,889
47 | TOTAL | 268,464,320 |  | 212,910,676 | 173,648,891 | 229,202,535

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfOtherDeferredCredits
Atlanta-Jacksonville Prepaid Fiber Maintenance and Right of Way Encroachment is being amortized over 10 years and 22 years ending in 2024 and 2025, respectively. Macon Ring and Macon Spur Prepaid Fiber is being amortized over 20 years and 24 years ending in 2027 and 2026, respectively.
(b) Concept: DescriptionOfOtherDeferredCredits
Deferred credits for Contributions in Aid of Construction (CIAC) are cash advances from customers related to capital projects which are used to offset CWIP costs when incurred. Prepaid on-going maintenance over $250K for CIAC requires amortization over the life of the asset.
(c) Concept: DescriptionOfOtherDeferredCredits
Prepaid Rent for Outdoor Lighting is amortized over a 24-month period beginning in the month the payment is received.
(d) Concept: DescriptionOfOtherDeferredCredits
Deferred revenue from Utility Service Contracts is being amortized over the life of the contract which is 25 years.
(e) Concept: DescriptionOfOtherDeferredCredits
Maintenance on Atlanta Airport network underground facilities at the End Around Relocation and Concourse is being amortized over 29 years ending 2036 and 35 years ending 2043, respectively. The Dekalb County Water Plant Substation is being amortized over 33 years ending in 2043.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
|  |  | CHANGES DURING YEAR | ADJUSTMENTS |
|  |  |  |  |  |  | Debits | Credits |
Line No. | Account (a) | Balance at Beginning of Year (b) | Amounts Debited to Account 410.1 (c) | Amounts Credited to Account 411.1 (d) | Amounts Debited to Account 410.2 (e) | Amounts Credited to Account 411.2 (f) | Account Credited (g) | Amount (h) | Account Debited (i) | Amount (j) | Balance at End of Year (k)
1 | Accelerated Amortization (Account 281) |  |  |  |  |  |  |  |  |  |
2 | Electric |  |  |  |  |  |  |  |  |  |
3 | Defense Facilities |  |  |  |  |  |  |  |  |  |
4 | Pollution Control Facilities | 564,996,931 | 12,179,841 | 70,382,737 |  |  | 182, 254 | 338 | 182, 254 | 22,780,142 | 529,573,839
5 | Other |  |  |  |  |  |  |  |  |  |
5.1 | Other (provide details in footnote): |  |  |  |  |  |  |  |  |  |
8 | TOTAL Electric (Enter Total of lines 3 thru 7) | 564,996,931 | 12,179,841 | 70,382,737 |  |  |  | 338 |  | 22,780,142 | 529,573,839
9 | Gas |  |  |  |  |  |  |  |  |  |
10 | Defense Facilities |  |  |  |  |  |  |  |  |  |
11 | Pollution Control Facilities |  |  |  |  |  |  |  |  |  |
12 | Other |  |  |  |  |  |  |  |  |  |
12.1 | Other (provide details in footnote): |  |  |  |  |  |  |  |  |  |
15 | TOTAL Gas (Enter Total of lines 10 thru 14) |  |  |  |  |  |  |  |  |  |
16 | Other |  |  |  |  |  |  |  |  |  |
16.1 | Other |  |  |  |  |  |  |  |  |  |
16.2 | Other |  |  |  |  |  |  |  |  |  |
17 | TOTAL (Acct 281) (Total of 8, 15 and 16) | 564,996,931 | 12,179,841 | 70,382,737 |  |  |  | 338 |  | 22,780,142 | 529,573,839
18 | Classification of TOTAL |  |  |  |  |  |  |  |  |  |
19 | Federal Income Tax | 461,495,236 | 8,198,170 | 61,620,887 |  |  | 182, 254 |  | 182, 254 | 22,780,142 | 430,852,661
20 | State Income Tax | 103,501,695 | 3,981,671 | 8,761,850 |  |  | 182, 254 | 338 | 182, 254 |  | 98,721,178
21 | Local Income Tax |  |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
|  |  | CHANGES DURING YEAR | ADJUSTMENTS |
|  |  |  |  |  |  | Debits | Credits |
Line No. | Account (a) | Balance at Beginning of Year (b) | Amounts Debited to Account 410.1 (c) | Amounts Credited to Account 411.1 (d) | Amounts Debited to Account 410.2 (e) | Amounts Credited to Account 411.2 (f) | Account Credited (g) | Amount (h) | Account Debited (i) | Amount (j) | Balance at End of Year (k)
1 | Account 282 |  |  |  |  |  |  |  |  |  |
2 | Electric | 4,354,043,340 | 21,213,607 | 2,254,760 |  |  | 182/254 | 35,265,120 | 182/254/282 | 93,692,988 | 4,393,512,361
3 | Gas |  |  |  |  |  |  |  |  |  |
4 | Other (Specify) | 7,561,656 | 608,012 | 33,808,023 |  |  |  |  |  |  | 40,761,667
5 | Total (Total of lines 2 thru 4) | 4,361,604,996 | 21,821,619 | 36,062,783 |  |  |  | 35,265,120 |  | 93,692,988 | 4,434,274,028
6 | Other Income and Deductions | 110,351,899 |  |  | 485,810,111 | 33,538 |  |  | 282 |  | 375,424,674
7 | CWIP Electric | 410,291,138 |  | 222,403,604 |  |  |  |  |  |  | 187,887,534
8 | CWIP NonElectric | 887,659,556 |  |  | 2,953,239 | 522,286,396 |  |  |  |  | 362,419,921
9 | TOTAL Account 282 (Total of Lines 5 thru 8) | 3,174,006,201 | 21,821,619 | 258,466,387 | 482,856,872 | 522,319,934 |  | 35,265,120 |  | 93,692,988 | 3,508,541,899
10 | Classification of TOTAL |  |  |  |  |  |  |  |  |  |
11 | Federal Income Tax | 2,580,207,024 | 24,718,362 | 190,660,339 | 370,779,119 | 406,127,916 | 182/254 | 28,780,319 | 182/254 | 83,839,797 | 2,836,557,276
12 | State Income Tax | 593,799,177 | 2,896,743 | 67,806,048 | 112,077,753 | 116,192,018 | 182/254 | 6,484,801 | 182/254 | 9,853,191 | 671,984,623
13 | Local Income Tax |  |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
|  |  | CHANGES DURING YEAR | ADJUSTMENTS |
|  |  |  |  |  |  | Debits | Credits |
Line No. | Account (a) | Balance at Beginning of Year (b) | Amounts Debited to Account 410.1 (c) | Amounts Credited to Account 411.1 (d) | Amounts Debited to Account 410.2 (e) | Amounts Credited to Account 411.2 (f) | Account Credited (g) | Amount (h) | Account Debited (i) | Amount (j) | Balance at End of Year (k)
1 | Account 283 |  |  |  |  |  |  |  |  |  |
2 | Electric |  |  |  |  |  |  |  |  |  |
3 | Premium on Reacquired Debt | 56,798,335 |  | 4,191,894 |  |  |  |  |  |  | 52,606,441
4 | Additional Pension Deduction | 411,670,612 | 34,048,156 | 26,023 |  |  |  |  |  |  | 445,692,745
5 | Other Basis Differences - 109 | 111,350,037 | 59,970 | 30,070 |  |  | 182/254 | 10,950,805 | 182/254 | 16,303,921 | 116,733,053
6 | Other * | 842,833,156 | 206,963,543 | 221,073,212 |  |  | 182/254 |  | 182/254 |  | (a) 828,723,487
9 | TOTAL Electric (Total of lines 3 thru 8) | 1,422,652,140 | 241,071,669 | 225,321,199 |  |  |  | 10,950,805 |  | 16,303,921 | 1,443,755,726
10 | Gas |  |  |  |  |  |  |  |  |  |
11 |  |  |  |  |  |  |  |  |  |  |
12 |  |  |  |  |  |  |  |  |  |  |
13 |  |  |  |  |  |  |  |  |  |  |
14 |  |  |  |  |  |  |  |  |  |  |
15 |  |  |  |  |  |  |  |  |  |  |
16 |  |  |  |  |  |  |  |  |  |  |
17 | TOTAL Gas (Total of lines 11 thru 16) |  |  |  |  |  |  |  |  |  |
18 | TOTAL Other | 40,404,883 |  |  |  | 11,229 |  |  |  |  | 40,416,112
19 | TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18) | 1,463,057,023 | 241,071,669 | 225,321,199 |  | 11,229 |  | 10,950,805 |  | 16,303,921 | 1,484,171,838
20 | Classification of TOTAL |  |  |  |  |  |  |  |  |  |
21 | Federal Income Tax | 1,125,223,087 | 186,364,131 | 179,697,434 |  | 11,229 | 182/254 | 8,775,806 | 182/254 | 12,939,341 | 1,136,064,548
22 | State Income Tax | 337,833,936 | 54,707,538 | 45,623,765 |  |  | 182/254 | 2,174,999 | 182/254 | 3,364,580 | 348,107,290
23 | Local Income Tax |  |  |  |  |  |  |  |  |  |
NOTES

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOther
| 12/31/2022 | DR 410.1 | CR 411.1 | Debit Adj | Credit Adj | 12/31/2023
Customer Advances on Const. | $ | (31,281,310) |  | $ | 8,124,694 |  | $ | (4,383,382) |  | $ | — |  | $ | — |  | $ | (27,539,998) |
Deferred Interest on |  |  |  |  |  |
Nuclear Fuel | 10,514,298 |  | 631,060 |  | (961,951) |  | — |  | — |  | 10,183,407 |
Deferred Jobs Revenue | 1,039,790 |  | 1,799,060 |  | (1,294,459) |  | — |  | — |  | 1,544,391 |
Emission Allowances | 1,930,085 |  | — |  | (4,153) |  | — |  | — |  | 1,925,932 |
Unbilled Rev. - Flat Bill | 8,922,561 |  | 20,972,660 |  | (20,693,227) |  | — |  | — |  | 9,201,994 |
Fuel Clause Recovery | 548,162,297 |  | 41,735,657 |  | (82,111,938) |  | — |  | — |  | 507,786,016 |
Levelized Purchase Power | 1,253,179 |  | 20,141,269 |  | (19,077,328) |  | — |  | — |  | 2,317,120 |
Nuclear Construction |  |  |  |  |  |
Cost Recovery | 13,072,668 |  | 1,985,869 |  | (3,765,033) |  | — |  | — |  | 11,293,504 |
Nuclear Outage | 7,924,580 |  | 6,992,818 |  | (6,213,051) |  | — |  | — |  | 8,704,347 |
Reg. Asset - Cloud |  |  |  |  |  |
Computing | 15,717,987 |  | 6,970,732 |  | (346,737) |  | — |  | — |  | 22,341,982 |
Reg. Asset - COVID-19 Costs | 6,719,908 |  | — |  | (2,239,969) |  | — |  | — |  | 4,479,939 |
Reg. Asset - Customer |  |  |  |  |  |
Usage Data Costs | 86,848 |  | 17,591 |  | (64,033) |  | — |  | — |  | 40,406 |
Reg. Asset - Deferred |  |  |  |  |  |
Plant Depreciation | — |  | 33,813,986 |  | — |  | — |  | — |  | 33,813,986 |
Reg. Asset - IQTBEE |  |  |  |  |  |
Program | 8,803 |  | — |  | (1,368) |  | — |  | — |  | 7,435 |
Reg. Asset - TOU MB |  |  |  |  |  |
Revenue Erosion | 338,221 |  | 207,358 |  | (191,465) |  | — |  | — |  | 354,114 |
Reg. Asset - Nuclear |  |  |  |  |  |
Financing | — |  | 3,640,558 |  | — |  | — |  | — |  | 3,640,558 |
Reg. Asset - Cancelled |  |  |  |  |  |
Construction Projects | (5,436) |  | 5,436 |  | — |  | — |  | — |  | — |
Reg. Asset - Obsolete Inv | 3,456,348 |  | 3,454,400 |  | (3,692,390) |  | — |  | — |  | 3,218,358 |
Reg. Asset - Retired Units | 253,079,651 |  | 764,538 |  | (32,886,221) |  | — |  | — |  | 220,957,968 |
Tax Legislative Adj | 1,892,678 |  | 29,921,534 |  | (31,814,212) |  | — |  | — |  | — |
Storm Damage | — |  | 25,784,327 |  | (11,332,298) |  | — |  | — |  | 14,452,029 |
| $ | 842,833,156 |  | $ | 206,963,546 |  | $ | (221,073,213) |  | $ | — |  | $ | — |  | $ | 828,723,488 |
NOTE 1: DITS associated with Premium on Reacquired Debt relate to the premium on the reacquisition of certain series of first mortgage and pollution control bonds. This loss on reacquisition is recognized for tax return purposes in the year incurred, but amortized over various periods for book purposes. NOTE 2: DITS on Additional Pension Deduction relate to actual pension costs that impact the pension fund and are currently recognized for tax return purposes. For book purposes, a deduction is taken as the pension costs are accrued. NOTE 3: DITS on Other Basis Differences - 109 represent the tax effects of temporary differences created with FAS 109. NOTE 4: DITS on Deferred Jobs Revenues represent revenues that have been billed for jobbing work done. The revenues are deferred on the books until all costs are accumulated. For tax purposes, the revenues are recognized currently. NOTE 5: DITS on Emission Allowances represent actual cash payments deducted on the tax return for the purchases of emission allowances versus book accounting, which accounts for the allowances using an average weighted cost basis. NOTE 6: DITS on Unbilled Revenues associated with Flat Bill program represent tax effect of differences between customer actual usage and contracted usage related revenues. NOTE 7: DITS on Fuel Clause Recovery relate to recognition of the under recovery of fuel costs in revenues for book purposes currently, while these revenues are recognized for tax purposes when actually collected. NOTE 8: DITS on Levelized Purchase Power relate to actual capacity expenses which are recognized as paid for tax purposes. For book purposes, these costs will be levelized over the term of the purchase agreement. NOTE 9: DITS on Nuclear Outage relate to expenses incurred during scheduled outages at nuclear facilities, which are deferred on the books per a GPSC retail rate order. For book purposes, these costs will be amortized over the GPSC mandated recovery period. For tax purposes, these costs are deducted as incurred. NOTE 10: DITS on Nuclear Construction Cost Recovery are related to the billed amounts to customers for the recovery of financing cost associated with building a nuclear plant. NOTE 11: DITS on Other Deferred Costs - Electric are miscellaneous temporary differences. NOTE 12: DITS on Regulatory Asset Obsolete Inventory are associated with the inventory determined to be obsolete related to the retirement of Plant Branch Units 3 and 4. NOTE 13: Regulatory Asset Cancelled Construction Projects are associated with the cost deferrals of cancelled construction projects for retired units. These cost are expected to be amortized for books over nine years beginning in January 2014. NOTE 14: DITS on Regulatory Assets Retired Units are associated with Net Book Value that will be amortized over the remaining useful life of the unit. NOTE 15: DITS on Customer Advances on Construction are funds received from customers for construction work requested by customer. For tax, the funds are taxable upon receipt. NOTE 16: DITS on Storm Damage represent actual costs deducted on the tax return as incurred, which have exceeded the book accrual allowed by the GPSC. NOTE 17: DITS On Tax Legislative Regulatory Adjustment represent deductions made to our Other Post Retirement Benefit balance related to the Medicare Subsidy. Federal tax laws changed our anticipated tax return deduction for future years related to retiree prescription drugs as a result of the subsidy now being taxable. NOTE 18: DITS on Other Income & Deductions represent the tax effect associated with FAS 133, Non-Utility Deferred Intercompany Gains, and miscellaneous differences. Deferred Intercompany Gains relate to the gain on the sale of transmission properties to Gulf Power Company (now Florida Power and Light Company), gain on the sale of computer equipment to Southern Company Services, and gain on sale of property to Southern Power Company. NOTE 19: DITS on State Tax Reform Legislation are related to the expected impact of the change in the state tax rate. NOTE 20: DITS on Regulatory Asset Customer Usage Data Costs represent costs to be recovered for acquiring customer usage data. NOTE 21: DITS on Deferred Interest Nuclear Fuel relate to the deferral of capitalized interest on nuclear fuel for Plant Vogtle Units 3 &4. NOTE 22: DITS on Reg. Asset – Cloud Computing are associated with the deferral of certain costs related to the implementation of new cloud based business applications used by the Company. NOTE 23: DITS on Reg. Asset - IQTBEE (Income Qualified Tariff Based on Energy Efficiency) are related to a program for retail customers that provides energy efficiency upgrades to income qualified customers. NOTE 24: DITS on Reg. Asset - COVID-19 costs are associated with recoverable costs from the COVID-19 pandemic. NOTE 25: DITS on Reg. Asset - TOU MB Revenue Erosion are related to the regulatory asset created for tracking revenue erosion from Georgia Power customers using the "time of use - medium business rate." NOTE 26: DITS on Reg. Asset - Deferred Plant Depreciation are related to the PSC approved deferral of depreciation for Plant Scherer Units 1-3, Bowen Units 1 & 2, and Vogtle Unit 3. NOTE 27: DITS on Reg. Asset - Nuclear Financing are related to the deferred financing costs on Vogtle Unit 3 as ordered by the PSC.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
|  |  | DEBITS |  |
Line No. | Description and Purpose of Other Regulatory Liabilities (a) | Balance at Beginning of Current Quarter/Year (b) | Account Credited (c) | Amount (d) | Credits (e) | Balance at End of Current Quarter/Year (f)
1 | (a) Deferred Income Taxes | 2,244,117,641 | 190,411 | 200,734,962 | 117,338,286 | 2,160,720,965
2 | (b) External Decommissioning Liability | 546,780,349 | 128 |  | 118,215,173 | 664,995,522
3 | (c) Asset Retirement Obligations | 443,663,918 | 182,411 | 305,458,502 | 178,648,505 | 316,853,921
4 | (d) Gas and Electric Hedges | 41,717,326 | Various | 41,717,326 | 11,471,020 | 11,471,020
5 | (e) DSM Over Recovery | 37,610,688 | 440,442 |  | 8,220,494 | 45,831,182
6 | (f) Retiree Benefit Plans | 79,233,273 | 926 | 21,460,042 | 47,136,157 | 104,909,388
7 | (g) Plant Retirements | 8,588,292 | 407.4 | 2,867,694 |  | 5,720,598
8 | (h) Nuclear Decommissioning | 7,565,252 | 407.4 | 3,152,188 | 16,141,391 | 20,554,455
41 | TOTAL | 3,409,276,739 |  | 575,390,714 | 497,171,026 | 3,331,057,051

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
The protected excess accumulated deferred income taxes associated with the remeasurement of Accumulated Deferred Income Taxes as a result of the Tax Cuts and Jobs Act are amortized over the related remaining property lives using the average rate assumption method in accordance with IRS normalization principles which may range up to 56 years.The deferred tax assets and regulatory liabilities associated with the remaining unamortized investment tax credits are being amortized over the related remaining property lives in accordance with IRS normalization principles which may range up to approximately 44 years.
| Beginning Balance | Amortized to 411.1 | Net DR/CR Adj | Ending Balance
Deferred Income Taxes | $ | 74,181,501 |  | $ | — |  | $ | 3,227,049 |  | $ | 77,408,550 |
Protected EADIT | $ | 2,169,936,140 |  | $ | (64,559,192) |  | $ | (22,064,533) |  | $ | 2,083,312,415 |
(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
Effective January 1, 2023, no funding will be accrued for the Plant Hatch Units 1 and 2 and Plant Vogtle Units 1 and 2 external nuclear decommissioning trusts until the next base rate case as ordered by the Georgia PSC in Docket No. 44280. Effective August 1, 2023, the Company is accruing $7.6 million annually until the next base rate case, as ordered by the Georgia PSC in Docket No. 43838, for the funding of future costs related to decommissioning Plant Vogtle Unit 3. As ordered by the Georgia PSC in Docket No. 29849, the Company will accrue $7.8 million annually starting the month after Plant Vogtle Unit 4 commercial operation, until the next base rate case, for the funding of future costs related to decommissioning Plant Vogtle Unit 4.
(c) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
Coal Combustion Residuals (CCR) AROs are recovered through the Environmental Compliance Cost Recovery tariff, with approximately $160 million recovered in 2023, and approximately $100 million and $325 million expected to be recovered in 2024 and 2025, respectively, with the recovery amount for future years updated through compliance filings. Approximately $17 million annually will be recovered for non-CCR AROs through traditional base tariffs. Other cost of removal obligations and non-CCR AROs are recovered over the related property lives, which may range up to 56 years.
(d) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
Realized and unrealized gains arising from marked to market gas and electric hedges are deferred and recovered when settled as ordered by the Georgia PSC in Docket No. 16134. The Company's natural gas hedging program uses an array of derivative instruments within a 36-month time horizon, as ordered by the Georgia PSC in Docket No. 43011.
(e) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
The costs associated with Demand-Side Management (DSM) initiatives are recovered through the DSM tariffs, and the revenues and expenses are trued-up based on actual results. The over or under recovery from the previous year is applied to the DSM tariffs in the year after a full calendar year through the annual compliance filings.
(f) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
The credits associated with retiree benefit plans resulted from a change in valuation methodology and are being amortized over 13 years ending December 31, 2032.
(g) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
In accordance with the Georgia PSC order in Docket No. 44280, the credit balance of the remaining net book values of Plant Boulevard Unit 1, Plant McIntosh Unit 1, and Plant Langdale Units 5 and 6 as of December 31, 2022 is being amortized over a three-year period ending December 31, 2025.
(h) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
In accordance with the Nuclear Regulatory Commission requirement to satisfy funding assurance for nuclear decommissioning, the Company provided funding to the external nuclear decommissioning trust for Plant Vogtle Unit 3 of $7.6 million in 2022. In 2023, the Company funded $0.8 million, $7.6 million, and $7.8 million related to Plant Vogtle Units 1, 3, and 4, respectively. Effective August 1, 2023, the Company is amortizing $7.6 million annually until the next base rate case, as ordered by the Georgia PSC in Docket No. 43838, for the funding of future costs related to decommissioning Plant Vogtle Unit 3. As ordered by the Georgia PSC in Docket No. 29849, the Company will amortize $7.8 million annually starting the month after Plant Vogtle Unit 4 commercial operation until the next base rate case, for the funding of future costs related to decommissioning Plant Vogtle Unit 4. The recovery of the $0.8 million of funding for Plant Vogtle Unit 1 will be determined by the Georgia PSC in the next base rate case.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No. | Title of Account (a) | Operating Revenues Year to Date Quarterly/Annual (b) | Operating Revenues Previous year (no Quarterly) (c) | MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d) | MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e) | AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f) | AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1 | SalesOfElectricityHeadingAbstract Sales of Electricity |  |  |  |  |  |
2 | ResidentialSalesAbstract (440) Residential Sales | 4,039,663,405 | 4,513,634,027 | 27,622,686 | 29,085,636 | 2,387,722 | 2,347,918
3 | CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales |  |  |  |  |  |
4 | CommercialSalesAbstract Small (or Comm.) (See Instr. 4) | 3,550,813,715 | 4,160,629,692 | 32,607,165 | 32,574,680 | 327,465 | 325,274
5 | IndustrialSalesAbstract Large (or Ind.) (See Instr. 4) | 1,535,076,602 | 2,255,410,817 | 23,475,989 | 23,851,133 | 10,661 | 10,674
6 | PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting | 82,560,322 | 86,094,743 | 280,071 | 301,346 | 9,412 | 9,486
7 | OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities |  |  |  |  |  |
8 | SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways | 10,512,196 | 13,696,636 | 144,124 | 143,691 | 1 | 1
9 | InterdepartmentalSalesAbstract (448) Interdepartmental Sales |  |  |  |  |  |
10 | SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers | 9,218,626,240 | 11,029,465,915 | 84,130,035 | 85,956,486 | 2,735,261 | 2,693,353
11 | SalesForResaleAbstract (447) Sales for Resale | 196,324,295 | 236,756,071 | 2,635,740 | 2,445,555 |  |
12 | SalesOfElectricityAbstract TOTAL Sales of Electricity | 9,414,950,535 | 11,266,221,986 | 86,765,775 | 88,402,041 | 2,735,261 | 2,693,353
13 | ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds | (a) 329,178 | 237,409,901 |  |  |  |
14 | RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds | 9,414,621,357 | 11,028,812,085 | 86,765,775 | 88,402,041 | 2,735,261 | 2,693,353
15 | OtherOperatingRevenuesAbstract Other Operating Revenues |  |  |  |  |  |
16 | ForfeitedDiscounts (450) Forfeited Discounts | 16,674,049 | 16,634,308 |  |  |  |
17 | MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues | (b) 270,534,357 | (d) 252,881,974 |  |  |  |
18 | SalesOfWaterAndWaterPower (453) Sales of Water and Water Power | 461,410 | 294,255 |  |  |  |
19 | RentFromElectricProperty (454) Rent from Electric Property | 27,144,036 | 24,681,487 |  |  |  |
20 | InterdepartmentalRents (455) Interdepartmental Rents |  |  |  |  |  |
21 | OtherElectricRevenue (456) Other Electric Revenues | (c) 56,512,086 | (e) 22,801,907 |  |  |  |
22 | RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others | 115,793,238 | 93,675,424 |  |  |  |
23 | RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues |  |  |  |  |  |
24 | MiscellaneousRevenue (457.2) Miscellaneous Revenues |  |  |  |  |  |
25 | OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues |  |  |  |  |  |
26 | OtherOperatingRevenues TOTAL Other Operating Revenues | 487,119,176 | 410,969,355 |  |  |  |
27 | ElectricOperatingRevenues TOTAL Electric Operating Revenues | 9,901,740,533 | 11,439,781,440 |  |  |  |
Line12, column (b) includes $ 21,013,539 of unbilled revenues.
Line12, column (d) includes 370,491 MWH relating to unbilled revenues

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: ProvisionForRateRefunds
Provision for rate refund
(b) Concept: MiscellaneousServiceRevenues
Miscellaneous Service Revenues (Account 451) | 2023
Outdoor Lighting | $ | 212,137,196 |
Transmission Maintenance Fees | 24,509,383 |
Account Charges | 17,897,944 |
Reconnect Fees | 8,509,177 |
Returned Check Fees | 6,177,509 |
Renewable Program Fees | 1,163,230 |
Miscellaneous Small Items (each under $250,000) | 139,918 |
Total Miscellaneous Service Revenues (Account 451) | $ | 270,534,357 |
(c) Concept: OtherElectricRevenue
Other Electric Revenues (Account 456) | 2023
Integrated Transmission System O&M Revenue | $ | 27,403,192 |
Rate Administration Charges | 6,721,302 |
Scheduling, System Control and Dispatching | 6,563,779 |
Spare Equipment Carrying Charge | 6,111,748 |
Compensation for Collecting Sales Tax | 3,750,156 |
Colocation | 2,287,798 |
Revenue from Operation of Fish and Wildlife | 2,264,028 |
Renewable Program Fees | 1,509,543 |
Miscellaneous Small Items (each under $250,000) | 1,482,884 |
Revenues from Additional Regulated Services | 1,403,500 |
Renewable Program Recurring Fees | 1,388,245 |
Joint Use Poles | 1,135,007 |
EV Charging Stations | 1,027,800 |
Transmission Interconnection Termination | 674,995 |
Encroachment Fees | 288,182 |
Land Related Revenue | 258,204 |
Realized loss on Price Protection Products | (3,893,149) |
Transmission Service Agreements | (3,865,128) |
Total Other Electric Revenues (Account 456) | $ | 56,512,086 |
(d) Concept: MiscellaneousServiceRevenues
Miscellaneous Service Revenues (Account 451) | 2022
Outdoor Lighting | $ | 188,961,094 |
Transmission Maintenance Fees | 29,668,661 |
Account Charges | 17,959,985 |
Reconnect Fees | 9,869,927 |
Returned Check Fees | 5,445,036 |
Renewable Program Fees | 853,979 |
Miscellaneous Small Items (each under $250,000) | 123,292 |
Total Miscellaneous Service Revenues (Account 451) | $ | 252,881,974 |
(e) Concept: OtherElectricRevenue
Other Electric Revenues (Account 456) | 2022
Integrated Transmission System O&M Revenue | $ | 23,307,518 |
Rate Administration Charges | 6,556,581 |
Scheduling, System Control and Dispatching | 4,593,915 |
Transmission Service Agreements | 4,329,662 |
PPA Admin | 4,178,435 |
Spare Equipment Carrying Charge | 3,876,781 |
Revenue from Operation of Fish and Wildlife | 3,648,485 |
Compensation for Collecting Sales Tax | 3,413,534 |
Colocation | 2,041,416 |
Miscellaneous Small Items (each under $250,000) | 1,316,919 |
Joint Use Poles | 734,387 |
Land Related Revenue | 488,505 |
Transmission Interconnection Termination | 450,000 |
EV Charging Stations | 355,036 |
Realized loss on Price Protection Products | (20,867,276) |
Renewable Program Fees | (15,621,991) |
Total Other Electric Revenues (Account 456) | $ | 22,801,907 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No. | Description of Service (a) | Balance at End of Quarter 1 (b) | Balance at End of Quarter 2 (c) | Balance at End of Quarter 3 (d) | Balance at End of Year (e)
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46 | TOTAL |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 | R-M Residential: Multi-Unit | 13,361 | 2,029,063 | 1,915 | 6,977 | 0.1519
2 | R Residential | 20,194,719 | 2,919,529,434 | 1,816,351 | 11,118 | 0.1446
3 | TOU-REO Time-of-Use - Residential Energy Only | 77,592 | 10,762,165 | 6,198 | 12,519 | 0.1387
4 | TOU-PEV Time-of-Use - Plug In Electric Vehicle | 200,207 | 26,264,653 | 10,685 | 18,737 | 0.1312
5 | OL_NGRE Outdoor Lighting | 41,197 | 14,198,686 | 4,321 | 9,534 | 0.3447
6 | OL-UN Outdoor Lighitng | 18,535 | 2,048,932 | 2,357 | 7,864 | 0.1105
7 | FLAR-R Flat Bill - Residential | 5,240,958 | 814,871,981 | 383,345 | 13,672 | 0.1555
8 | FLAT-GS Flat Bill - General Service | 179 | 44,742 | 29 | 6,160 | 0.2504
9 | PLS-R Power & Light - Small | 33,295 | 4,621,566 | 743 | 44,812 | 0.1388
10 | PLM-R Power & Light - Medium | 108,991 | 12,352,243 | 172 | 633,670 | 0.1133
11 | PLL-R Power & Light - Large | 36,250 | 4,580,637 | 11 | 3,295,476 | 0.1264
12 | Pre pay | 1,014,782 | 152,953,201 | 79,197 | 12,813 | 0.1507
13 | TOU-RD Time-of-Use - Residential Demand | 783,759 | 129,060,409 | 78,839 | 9,941 | 0.1647
14 | GS-R General Service | 10,964 | 3,562,579 | 3,559 | 3,081 | 0.3249
41 | TOTAL Billed Residential Sales | 27,774,789 | 4,096,880,291 | 2,387,722 | 11,632 | 0.1475
42 | TOTAL Unbilled Rev. (See Instr. 6) | 152,103 | 57,216,886 |  |  | 0.3762
43 | TOTAL | 27,622,686 | 4,039,663,405 | 2,387,722 | 11,569 | 0.1462

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 | SCH School Service | 153,413 | 22,921,239 | 1,035 | 148,225 | 0.1494
2 | SLM School Load Management | 1,673,117 | 166,356,706 | 1,284 | 1,303,051 | 0.0994
3 | TOU-HLF Time of Use - High Load Factor | 57,281 | 5,551,079 | 15 | 3,818,749 | 0.0969
4 | OLNG-BB Outdoor Lighting | 12,933 | 1,433,143 | 2,398 | 5,393 | 0.1108
5 | OL-NGRE Outdoor Lighting | 60,525 | 13,243,647 | 4,615 | 13,115 | 0.2188
6 | RTPHSLM Real Time Pricing Hour Ahead - School Load Management | 37,959 | 2,661,219 | 1 | 37,959,118 | 0.0701
7 | RTPDSCH Real Time Pricing Day Ahead - School Service | 129,148 | 10,189,059 | 76 | 1,699,317 | 0.0789
8 | RTPDSCH Real Time Pricing Day Ahead - School Load Management | 551,480 | 44,463,186 | 186 | 2,964,945 | 0.0806
9 | OL-UN Outdoor Lighting | 310,620 | 34,473,219 | 19,390 | 16,020 | 0.1110
10 | UC Unmetered Communication | 105,332 | 21,719,192 | 17,363 | 6,066 | 0.2062
11 | FLAT-GS Flat Bill - General Service | 66,821 | 14,749,321 | 7,200 | 9,281 | 0.2207
12 | RTPDHLF RTP Day Ahead - Time of Use High Load Factor | 208,069 | 17,739,931 | 49 | 4,246,311 | 0.0853
13 | TOU-MB Time of Use - Multiple Business | 669,154 | 79,666,915 | 2,954 | 226,525 | 0.1191
14 | PLS-C Power & Light - Small | 2,955,610 | 463,059,200 | 62,300 | 47,441 | 0.1567
15 | PLM-C Power & Light - Medium | 9,474,981 | 1,245,875,629 | 33,089 | 286,340 | 0.1315
16 | PLL-C Power & Light - Large | 1,763,876 | 201,639,811 | 368 | 4,793,140 | 0.1143
17 | TOUGSD-C Time of Use - General Service Demand | 279,067 | 35,573,185 | 408 | 683,987 | 0.1275
18 | OGS-C Optional General Service | 3,232 | 912,271 | 167 | 19,355 | 0.2822
19 | IOP-C Irrigation Off-Peak | 39,845 | 5,755,526 | 695 | 57,331 | 0.1444
20 | G-C Governmental | 97,415 | 9,540,944 | 11 | 8,855,930 | 0.0979
21 | GS-C General Service | 1,229,893 | 277,885,587 | 163,700 | 7,513 | 0.2259
22 | TOUEO-C Time-of-Use - Energy Only | 551,174 | 81,828,772 | 6,446 | 85,506 | 0.1485
23 | SASND-C Seasonal Agricultural Service - Non-Demand | 979 | 159,534 | 28 | 34,968 | 0.1629
24 | RTPHPLLC Real Time Pricing Hour Ahead - Power & Light Large | 2,264,746 | 127,528,954 | 19 | 119,197,137 | 0.0563
25 | RTPHGC RTP Hour Ahead/G-COM | 188,088 | 13,180,940 | 3 | 62,696,104 | 0.0701
26 | RTPGOVC Real Time Pricing Day Ahead - Governmental | 126,213 | 11,061,192 | 7 | 18,030,490 | 0.0876
27 | RTGSDC Real Time Pricing Day Ahead - Time of Use - General Service Demand | 131,625 | 12,588,897 | 38 | 3,463,821 | 0.0956
28 | RTPDPLLC Real Time Pricing Day Ahead - Power & Light Large | 2,453,659 | 214,507,959 | 245 | 10,014,934 | 0.0874
29 | RTPDPLMC Real Time Pricing Day Ahead - Power & Light Medium | 2,557,056 | 181,726,210 | 945 | 2,705,879 | 0.0711
30 | FPA- COM Fixed Pricing Alternative | 762,428 | 67,776,652 | 165 | 4,620,775 | 0.0889
31 | SAS-COM Seasonal Agricultural Service | 20,670 | 2,282,366 | 199 | 103,871 | 0.1104
32 | APS-COM Agricultural Process Service | 9,450 | 1,038,550 | 43 | 219,759 | 0.1099
33 | FSTOU-C Farm Service | 66,200 | 8,570,705 | 1,786 | 37,066 | 0.1295
34 | RTPDTEOC Real Time Pricing Day Ahead - Time of Use | 4,919 | 299,453 | 5 | 983,707 | 0.0609
35 | TOUSCFC Time of Use - Supplier Choice FPO | 94,708 | 3,517,843 | 41 | 2,309,958 | 0.0371
36 | RTDFPAC RTP Day Ahead - Fixed Pricing Alternative | 48,710 | 4,754,970 | 11 | 4,428,142 | 0.0976
37 | TOUSC-C Time of Use Supplier Choice | 127,262 | 7,651,484 | 43 | 2,959,588 | 0.0601
38 | TOURN-C Time of Use Revenue Neutral | 303,475 | 28,396,375 | 54 | 5,619,910 | 0.0936
39 | RTDRN-C RTP Day Ahead - Revenue Neutral | 1,050,703 | 81,071,340 | 69 | 15,227,580 | 0.0772
40 | RTHRN-C RTP Hour Ahead - Revenue Neutral | 1,952,894 | 111,928,363 | 10 | 195,289,362 | 0.0573
41 | RTDPLSC RTP Day Ahead - Power & Light Supplier Choice | 15,693 | 801,182 | 4 | 3,923,213 | 0.0511
41 | TOTAL Billed Small or Commercial | 32,610,423 | 3,636,081,750 | 327,465 | 99,584 | 0.1115
42 | TOTAL Unbilled Rev. Small or Commercial (See Instr. 6) | 3,258 | 85,268,035 |  |  | 26.1699
43 | TOTAL Small or Commercial | 32,607,165 | 3,550,813,715 | 327,465 | 99,574 | 0.1089

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 | OL-NGRE Outdoor Lighting | 2,289 | 500,931 | 137 | 16,710 | 0.2188
2 | OL-UN Outdoor Lighting | 15,052 | 1,645,794 | 412 | 36,534 | 0.1093
3 | FLAT-GS Flat Bill - General Service | 203 | 51,898 | 33 | 6,157 | 0.2554
4 | PLS-I Power & Light - Small | 61,885 | 9,199,098 | 1,234 | 50,150 | 0.1486
5 | PLM-I Power & Light - Medium | 985,195 | 125,911,162 | 2,294 | 429,466 | 0.1278
6 | PLL-I Power & Light - Large | 598,061 | 68,384,269 | 125 | 4,784,491 | 0.1143
7 | TOUGSD-I Time of Use - General Service Demand | 192,588 | 24,573,726 | 163 | 1,181,520 | 0.1276
8 | OGS-I Optional General Service | 8,006 | 1,876,530 | 72 | 111,200 | 0.2344
9 | IOP-I Irrigation Off-Peak | 2,828 | 266,524 | 17 | 166,349 | 0.0942
10 | GS- I General Service | 29,320 | 6,853,321 | 4,450 | 6,587 | 0.2337
11 | TOUEO-I Time-of-Use - Energy Only | 43,502 | 6,310,343 | 513 | 84,800 | 0.1451
12 | SASND-I Seasonal Agricultural Service - Non-Demand | 500 | 85,227 | 17 | 29,433 | 0.1703
13 | RTPHPLLI Real Time Pricing Hour Ahead - Power & Light Large | 4,765,864 | 256,281,502 | 59 | 80,777,348 | 0.0538
14 | RTHPLMI Real Time Pricing Hour Ahead - Power & Light Medium | 601,280 | 27,857,047 | 9 | 66,808,839 | 0.0463
15 | RTPDGSDI Real Time Pricing Day Ahead - Time of Use - General Service Demand | 201,170 | 16,678,459 | 40 | 5,029,246 | 0.0829
16 | RTPHGSDI Real Time Pricing Hour Ahead - Time of Use - General Service Demand | 51,056 | 2,336,245 | 2 | 25,527,886 | 0.0458
17 | RTPDPLLI Real Time Pricing Day Ahead - Power & Light Large | 2,631,051 | 194,902,127 | 196 | 13,423,729 | 0.0741
18 | RTDPLMI Real Time Pricing Day Ahead - Power & Light Medium | 1,519,363 | 86,917,187 | 293 | 5,185,541 | 0.0572
19 | FPA-IND Fixed Pricing Alternative | 1,313,820 | 101,869,099 | 122 | 10,769,016 | 0.0775
20 | SASIND Seasonal Agricultural Service | 7,300 | 743,102 | 57 | 128,070 | 0.1018
21 | APS-IND Agricultural Process Service | 56,707 | 5,302,730 | 99 | 572,793 | 0.0935
22 | FSTOU-I Farm Service Time of Use | 361 | 43,069 | 7 | 51,501 | 0.1195
23 | RTHTEOI Real Time Pricing Hour Ahead - Time Of Use - Energy Only | 24,713 | 1,227,364 | 1 | 24,712,545 | 0.0497
24 | RTDTEOI Real Time Pricing Day Ahead - Time Of Use - Energy Only | 2,666 | 169,172 | 4 | 666,486 | 0.0635
25 | RTPDAPSI Real Time Pricing Day Ahead - Agricultural Process Service | 34,951 | 1,940,174 | 5 | 6,990,238 | 0.0555
26 | TOUSCFI Time of Use Supplier Choice FPO | 392,773 | 13,122,342 | 10 | 39,277,305 | 0.0334
27 | RTDFPAI RTP Day Ahead - Fixed Pricing Alternative | 188,144 | 14,357,736 | 18 | 10,452,431 | 0.0763
28 | TOUSCI Time of Use Supplier Choice | 192,055 | 14,227,125 | 7 | 27,436,497 | 0.0741
29 | RTHFPAI RTP Hour Ahead - Fixed Pricing Alternative | 269,574 | 16,715,406 | 3 | 89,858,057 | 0.0620
30 | TOURN-I Time of Use Revenue Neutral | 735,786 | 63,038,923 | 73 | 10,079,262 | 0.0857
31 | RTDRN-I RTP Day Ahead - Revenue Neutral | 1,882,216 | 143,255,745 | 104 | 18,098,230 | 0.0761
32 | RTHRN-I RTP Hour Ahead - Revenue Neutral | 5,990,674 | 344,900,894 | 57 | 105,099,563 | 0.0576
33 | RTDPLSI RTP Day Ahead/PLS-IND | 185,554 | 7,170,392 | 4 | 46,388,544 | 0.0386
34 | RTHPLSI RTP Hour Ahead/PLS-IND | 151,253 | 5,077,511 | 1 | 151,253,460 | 0.0336
35 | TOUMBI Time of Use --Multiple business | 1,810 | 202,657 | 22 | 82,262 | 0.1120
36 | EAF-IND Electric Arc Furnace | 322,227 | 19,358,663 | 1 | 322,226,950 | 0.0601
41 | TOTAL Billed Large (or Ind.) Sales | 23,461,797 | 1,583,353,494 | 10,661 | 2,200,506 | 0.0675
42 | TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6) | 14,192 | 48,276,892 |  |  | 3.4018
43 | TOTAL Large (or Ind.) | 23,475,989 | 1,535,076,602 | 10,661 | 2,201,837 | 0.0654

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 | RLG Roadway Lighting Governmental | 123,604 | 57,853,005 | 1,051 | 117,605 | 0.4681
2 | OL-Govt Outdoor Lighting - Governmental | 117,261 | 22,547,706 | 3,267 | 35,893 | 0.1923
3 | TC Traffic Control | 36,024 | 2,274,479 | 4,524 | 7,963 | 0.0631
4 | OL-UN Outdoor Lighting | 374 | 41,208 | 35 | 10,686 | 0.1102
5 | TC-M Traffic Control Metered | 2,808 | 339,874 | 535 | 5,248 | 0.1210
41 | TOTAL Billed Public Street and Highway Lighting | 280,071 | 83,056,272 | 9,412 | 29,757 | 0.2966
42 | TOTAL Unbilled Rev. (See Instr. 6) |  | 495,950 |  |  |
43 | TOTAL | 280,071 | 82,560,322 | 9,412 | 29,757 | 0.2948

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 | Marta Electric Transportation | 144,124 | 10,654,878 | 1 | 144,123,821 | 0.0739
41 | TOTAL Billed Sales To Railroads and Railways | 144,124 | 10,654,878 | 1 | 144,123,821 | 0.0739
42 | TOTAL Unbilled Rev. (See Instr. 6) |  | 142,682 |  |  |
43 | TOTAL | 144,124 | 10,512,196 | 1 | 144,123,821 | 0.0729

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
1 |  |  |  |  |  |
2 |  |  |  |  |  |
3 |  |  |  |  |  |
4 |  |  |  |  |  |
5 |  |  |  |  |  |
6 |  |  |  |  |  |
7 |  |  |  |  |  |
8 |  |  |  |  |  |
9 |  |  |  |  |  |
10 |  |  |  |  |  |
11 |  |  |  |  |  |
12 |  |  |  |  |  |
13 |  |  |  |  |  |
14 |  |  |  |  |  |
15 |  |  |  |  |  |
16 |  |  |  |  |  |
17 |  |  |  |  |  |
18 |  |  |  |  |  |
19 |  |  |  |  |  |
20 |  |  |  |  |  |
21 |  |  |  |  |  |
22 |  |  |  |  |  |
23 |  |  |  |  |  |
24 |  |  |  |  |  |
25 |  |  |  |  |  |
26 |  |  |  |  |  |
27 |  |  |  |  |  |
28 |  |  |  |  |  |
29 |  |  |  |  |  |
30 |  |  |  |  |  |
31 |  |  |  |  |  |
32 |  |  |  |  |  |
33 |  |  |  |  |  |
34 |  |  |  |  |  |
35 |  |  |  |  |  |
36 |  |  |  |  |  |
37 |  |  |  |  |  |
38 |  |  |  |  |  |
39 |  |  |  |  |  |
40 |  |  |  |  |  |
41 | TOTAL Billed Provision For Rate Refunds |  |  |  |  |
42 | TOTAL Unbilled Rev. (See Instr. 6) |  |  |  |  |
43 | TOTAL |  | (a) 329,178 |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: ProvisionForRateRefunds
Provision for rate refund

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No. | Number and Title of Rate Schedule (a) | MWh Sold (b) | Revenue (c) | Average Number of Customers (d) | KWh of Sales Per Customer (e) | Revenue Per KWh Sold (f)
41 | TOTAL Billed - All Accounts | 84,271,204 | 9,410,026,685 | 2,735,261 | 146,465,300 |
42 | TOTAL Unbilled Rev. (See Instr. 6) - All Accounts | 141,169 | (a) 191,400,445 |  |  |
43 | TOTAL - All Accounts | 84,130,035 | 9,218,626,240 | 2,735,261 | 146,465,300 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: RevenueFromSalesOfElectricityByRateSchedulesUnbilled
The Total Unbilled Rev included in total sales of electricity on pg 300 line 12 is ($191,400,445). The Total Unbilled Rev on pg 304 line 47 includes ($33,698,823.98) of Unbilled Revenue. The difference of ($157,701,621.26) is adjustments including:
FCR | $ | (144,446,776) |
NCCR | (6,673,439) |
DSM | (8,220,494) |
Flatbill Revenue Recognition | 1,048,118 |
Miscellaneous | 590,970 |
Total Difference | $ | (157,701,621) |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
|  |  |  |  | ACTUAL DEMAND (MW) |  | REVENUE |
Line No. | Name of Company or Public Authority (Footnote Affiliations) (a) | Statistical Classification (b) | FERC Rate Schedule or Tariff Number (c) | Average Monthly Billing Demand (MW) (d) | Average Monthly NCP Demand (e) | Average Monthly CP Demand (f) | Megawatt Hours Sold (g) | Demand Charges ($) (h) | Energy Charges ($) (i) | Other Charges ($) (j) | Total ($) (h+i+j) (k)
1 | Associated Energy Cooperative Inc. | OS | T4 |  |  |  | 2,970 |  | 102,507 |  | 102,507
2 | City of Dalton, Dalton Utilities | LU | T4 |  |  |  | 9,112 | 390,758 | 465,213 |  | 855,971
3 | City of Tallahassee, Florida | OS | T4 |  |  |  | 979 |  | 46,403 |  | 46,403
4 | City of Troy, Alabama | OS | T5 |  |  |  |  |  | 84,942 |  | 84,942
5 | Constellation Energy | OS | T5 |  |  |  |  |  | 104,255 |  | 104,255
6 | Dominion Energy | OS | T4 |  |  |  | 10,547 |  | 492,102 |  | 492,102
7 | Duke Energy Carolinas, LLC | OS | T4 |  |  |  | 7,464 |  | 216,321 |  | 216,321
8 | Duke Energy Florida | OS | T4 |  |  |  | 12,375 |  | 603,679 |  | 603,679
9 | Eagle Energy Partners I, L.P. | OS | T4 |  |  |  | 4,195 |  | 162,355 |  | 162,355
10 | Endure Energy, LLC | OS | T4 |  |  |  |  |  |  |  |
11 | Energy United Electric Membership Corporation | LU | T4 |  |  |  | 162,730 | 25,627,878 | 6,672,791 |  | 32,300,669
12 | Exelon Generation Company, LLC | OS | T4 |  |  |  | 22,666 |  | 741,483 |  | 741,483
13 | Flint EMC | LU | T4 |  |  |  | 122,331 | 16,764,940 | 4,967,470 |  | 21,732,410
14 | Florida Power & Light Company | OS | T4 |  |  |  | 9,709 |  | 553,514 |  | 553,514
15 | KGen Sandersville LLC | OS | T5 |  |  |  |  |  | 7,520 |  | 7,520
16 | Louisville Gas & Electric | OS | 0 |  |  |  | 129 |  | 3,024 |  | 3,024
17 | Macquarie Energy, LLC | OS | T4 |  |  |  | 65,205 |  | 3,174,702 |  | 3,174,702
18 | Mercuria Energy America, Inc | OS | T4 |  |  |  | 9,257 |  | 498,418 |  | 498,418
19 | Midwest Independent Trans System | OS | T4 |  |  |  | 23,100 |  | 337,337 |  | 337,337
20 | Morgan Stanley Capital Group, Inc. | OS | T4 |  |  |  | 14,619 |  | 665,988 |  | 665,988
21 | Municipal Electric Authority Of Georgia | OS | T4 |  |  |  | 918,808 | 32,800 | 55,717,015 |  | 55,749,815
22 | NextEra Gulf | OS | RS-138 |  |  |  |  |  |  |  |
23 | North Carolina EMC | OS | T4 |  |  |  | 2,736 |  | 80,680 |  | 80,680
24 | NTE Carolinas | OS | T4 |  |  |  | 21 |  | 941 |  | 941
25 | Oglethorpe Power Corporation | OS | T4 |  |  |  | 6,714 |  | 277,960 |  | 277,960
26 | Orlando Utilities Commission | OS | T4 |  |  |  | 1,832 |  | 70,505 |  | 70,505
27 | PJM Interconnection | OS | T4 |  |  |  | 6,398 |  | 184,785 |  | 184,785
28 | PowerSouth Energy Cooperative | OS | T4 |  |  |  | 866 | 58,680 | 299,720 |  | 358,400
29 | Rainbow Energy Marketing Corporation | OS | T4 |  |  |  | 7,652 |  | 373,386 |  | 373,386
30 | Santa Rosa | OS | T5 |  |  |  |  |  |  |  |
31 | Seminole Electric Cooperative | OS | T4 |  |  |  | 183,562 | 2,311,891 | 6,061,603 |  | 8,373,494
32 | South Carolina Electric & Gas Company | OS | T4 |  |  |  |  |  | 1,522 |  | 1,522
33 | South Carolina Public Service Authority | OS | T4 |  |  |  | 678 | 1,282,064 | 23,112 |  | 1,305,176
34 | South Mississippi Electric Power Association | OS | T4 |  |  |  |  |  | 47,785 |  | 47,785
35 | Southern Company Services | OS | RS-138 |  |  |  | 299,445 | 11,711,953 | 10,466,050 |  | 22,178,003
36 | Southwest Power Pool, Inc | OS | T4 |  |  |  |  |  |  |  |
37 | Tampa Electric Company | OS | T4 |  |  |  | 16,747 |  | 865,272 |  | 865,272
38 | Tennessee Valley Authority | OS | T4 |  |  |  | 112,866 | 9,312,524 | 11,128,302 |  | 20,440,826
39 | The Energy Authority | OS | T4 |  |  |  | 571,160 | 3,950,100 | 16,877,232 |  | 20,827,332
40 | Tri-County EMC | LU | T4 |  |  |  | 1,704 |  | 98,835 |  | 98,835
41 | Washington County Power, LLC (Mackinaw Power) | OS | T5 |  |  |  |  |  |  |  |
42 | Westar Energy, Inc. | OS | T4 |  |  |  |  |  |  |  |
43 | Southeastern Power Administration | OS | T4 |  |  |  | 25,787 |  | 1,034,328 |  | 1,034,328
44 | Walton Electric Membership Corporation | OS | T4 |  |  |  | 1,377 | 1,323,432 | 47,045 |  | 1,370,477
45 | Entergy Services | OS | T4 |  |  |  |  |  | 361 |  | 361
46 | Jacksonville Electric Authority | OS | T4 |  |  |  |  |  | 813 |  | 813
15 | Subtotal - RQ |  |  |  |  |  |  |  |  |  |
16 | Subtotal-Non-RQ |  |  |  |  |  | 2,635,740 | 72,767,020 | 123,557,275 |  | 196,324,295
17 | Total |  |  |  |  |  | 2,635,740 | 72,767,020 | 123,557,275 |  | 196,324,295

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No. | Account (a) | Amount for Current Year (b) | Amount for Previous Year (c) (c)
1 | PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES |  |
2 | SteamPowerGenerationAbstract A. Steam Power Generation |  |
3 | SteamPowerGenerationOperationAbstract Operation |  |
4 | OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering | 15,429,506 | 17,327,557
5 | FuelSteamPowerGeneration (501) Fuel | 748,302,685 | 641,245,781
6 | SteamExpensesSteamPowerGeneration (502) Steam Expenses | 26,517,436 | 15,955,166
7 | SteamFromOtherSources (503) Steam from Other Sources |  |
8 | SteamTransferredCredit (Less) (504) Steam Transferred-Cr. |  |
9 | ElectricExpensesSteamPowerGeneration (505) Electric Expenses | 17,473,063 | 15,904,526
10 | MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses | 45,010,448 | 39,152,777
11 | RentsSteamPowerGeneration (507) Rents |  |
12 | Allowances (509) Allowances | 18,535 | 15,818
13 | SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12) | 852,751,673 | 729,601,625
14 | SteamPowerGenerationMaintenanceAbstract Maintenance |  |
15 | MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering | 11,016,298 | 13,439,495
16 | MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures | 10,768,285 | 19,257,216
17 | MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant | 57,573,787 | 72,778,180
18 | MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant | 9,974,878 | 10,907,208
19 | MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant | 4,889,455 | 5,629,049
20 | SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19) | 94,222,703 | 122,011,148
21 | PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20) | 946,974,376 | 851,612,773
22 | NuclearPowerGenerationAbstract B. Nuclear Power Generation |  |
23 | NuclearPowerGenerationOperationAbstract Operation |  |
24 | OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering | 102,754,490 | 87,308,913
25 | NuclearFuelExpense (518) Fuel | 144,301,898 | 122,119,830
26 | CoolantsAndWater (519) Coolants and Water | 11,215,929 | 8,897,254
27 | SteamExpensesNuclearPowerGeneration (520) Steam Expenses | 15,322,228 | 12,290,634
28 | SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources |  |
29 | SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr. |  |
30 | ElectricExpensesNuclearPowerGeneration (523) Electric Expenses | 102,444 | 203,492
31 | MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses | 132,657,925 | 122,726,712
32 | RentsNuclearPowerGeneration (525) Rents | 587,867 | 657,392
33 | NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32) | 406,942,781 | 354,204,227
34 | NuclearPowerGenerationMaintenanceAbstract Maintenance |  |
35 | MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering | 26,808,048 | 21,649,067
36 | MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures | 3,626,312 | 5,021,341
37 | MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment | 8,581,498 | 13,650,464
38 | MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant | 10,968,683 | 13,404,054
39 | MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant | 23,405,535 | 15,906,614
40 | NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39) | 73,390,076 | 69,631,540
41 | PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40) | 480,332,857 | 423,835,767
42 | HydraulicPowerGenerationAbstract C. Hydraulic Power Generation |  |
43 | HydraulicPowerGenerationOperationAbstract Operation |  |
44 | OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering | 11,384,846 | 10,838,773
45 | WaterForPower (536) Water for Power | 1,907,526 | 1,853,297
46 | HydraulicExpenses (537) Hydraulic Expenses | 3,337,436 | 2,185,328
47 | ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses | 5,268,089 | 5,002,759
48 | MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses | 6,237,494 | 5,769,099
49 | RentsHydraulicPowerGeneration (540) Rents | 50,573 | 51,125
50 | HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49) | 28,185,964 | 25,700,381
51 | HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued) |  |
52 | HydraulicPowerGenerationMaintenanceAbstract Maintenance |  |
53 | MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering | 19,617 | 200,836
54 | MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures | 3,210,383 | 9,963,336
55 | MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways | 1,615,274 | 4,740,088
56 | MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant | 4,809,157 | 5,047,619
57 | MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant | 1,022,743 | 906,290
58 | HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57) | 10,677,174 | 20,858,169
59 | PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58) | 38,863,138 | 46,558,550
60 | OtherPowerGenerationAbstract D. Other Power Generation |  |
61 | OtherPowerGenerationOperationAbstract Operation |  |
62 | OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering | 9,083,028 | 8,541,479
63 | Fuel (547) Fuel | 888,871,830 | 1,722,485,510
64 | GenerationExpenses (548) Generation Expenses | 9,405,789 | 10,240,179
64.1 | OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment |  |
65 | MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses | 23,171,667 | 31,060,799
66 | RentsOtherPowerGeneration (550) Rents | 6,193 | 5,587
67 | OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67) | 930,538,507 | 1,772,333,554
68 | OtherPowerGenerationMaintenanceAbstract Maintenance |  |
69 | MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering | 5,287,071 | 7,946,019
70 | MaintenanceOfStructures (552) Maintenance of Structures | 9,984,620 | 10,851,373
71 | MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant | 47,286,336 | 39,633,875
71.1 | MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment |  |
72 | MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant | 2,531,062 | 2,438,197
73 | OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72) | 65,089,089 | 60,869,464
74 | PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73) | 995,627,596 | 1,833,203,018
75 | OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses |  |
76 | PurchasedPower (555) Purchased Power | 1,314,344,529 | 2,284,753,973
76.1 | PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations |  |
77 | SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching | 3,232,561 | 3,859,399
78 | OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses | 27,095,795 | 21,068,781
79 | OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78) | 1,344,672,885 | 2,309,682,153
80 | PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79) | 3,806,470,852 | 5,464,892,261
81 | TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES |  |
82 | TransmissionExpensesOperationAbstract Operation |  |
83 | OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering | 5,851,805 | 7,529,389
85 | LoadDispatchReliability (561.1) Load Dispatch-Reliability | 6,474,378 | 6,872,688
86 | LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System | 7,051,466 | 9,081,285
87 | LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling | 362,718 | 249,933
88 | SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services |  |
89 | ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development | 4,964,002 | 3,914,361
90 | TransmissionServiceStudies (561.6) Transmission Service Studies | 215,737 | 150,603
91 | GenerationInterconnectionStudies (561.7) Generation Interconnection Studies | 496,526 | 433,615
92 | ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services |  |
93 | StationExpensesTransmissionExpense (562) Station Expenses | 7,219,637 | 6,516,413
93.1 | OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment |  |
94 | OverheadLineExpense (563) Overhead Lines Expenses | 841,839 | 2,198,442
95 | UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses |  |
96 | TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others | 8,038,903 | 5,314,696
97 | MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses | 21,044,694 | 18,780,513
98 | RentsTransmissionElectricExpense (567) Rents | 47,968,913 | 38,980,260
99 | TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98) | 14,592,792 | 22,061,678
100 | TransmissionMaintenanceAbstract Maintenance |  |
101 | MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering | 14,306,185 | 17,356,883
102 | MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures | 215,915 | 203,738
103 | MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware | 11,162,038 | 3,023,881
104 | MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software | 1,792,606 | 878,395
105 | MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment | 1 | 6,100
106 | MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant |  |
107 | MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment | 13,437,252 | 21,591,223
107.1 | MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment |  |
108 | MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines | 23,865,864 | 49,032,891
109 | MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines | 3,065 | 322,269
110 | MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant | 825,994 | 1,713,819
111 | TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110) | 65,602,788 | 94,129,199
112 | TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111) | 80,195,580 | 116,190,877
113 | RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES |  |
114 | RegionalMarketExpensesOperationAbstract Operation |  |
115 | OperationSupervision (575.1) Operation Supervision |  |
116 | DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation |  |
117 | TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation |  |
118 | CapacityMarketAdministration (575.4) Capacity Market Facilitation |  |
119 | AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation |  |
120 | MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance |  |
121 | MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services |  |
122 | RentsRegionalMarketExpenses (575.8) Rents |  |
123 | RegionalMarketOperationExpense Total Operation (Lines 115 thru 122) |  |
124 | RegionalMarketExpensesMaintenanceAbstract Maintenance |  |
125 | MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements |  |
126 | MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware |  |
127 | MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software |  |
128 | MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment |  |
129 | MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant |  |
130 | RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129) |  |
131 | RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130) |  |
132 | DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES |  |
133 | DistributionExpensesOperationAbstract Operation |  |
134 | OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering | 21,846,425 | 24,567,564
135 | LoadDispatching (581) Load Dispatching | 6,923,805 | 8,315,033
136 | StationExpensesDistribution (582) Station Expenses | 669,684 | 1,365,610
137 | OverheadLineExpenses (583) Overhead Line Expenses | 2,099,991 | 2,506,397
138 | UndergroundLineExpenses (584) Underground Line Expenses | 15,794,163 | 20,760,781
138.1 | OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment |  |
139 | StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses | 269 | 515
140 | MeterExpenses (586) Meter Expenses | 29,917,171 | 31,085,224
141 | CustomerInstallationsExpenses (587) Customer Installations Expenses | 2,451,932 | 2,977,012
142 | MiscellaneousDistributionExpenses (588) Miscellaneous Expenses | 45,702,847 | 49,844,869
143 | RentsDistributionExpense (589) Rents | 4,068,362 | 3,314,278
144 | DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143) | 129,474,649 | 144,737,283
145 | DistributionExpensesMaintenanceAbstract Maintenance |  |
146 | MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering | 13,795,482 | 15,063,647
147 | MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures | 380,507 | 1,102,000
148 | MaintenanceOfStationEquipment (592) Maintenance of Station Equipment | 11,827,561 | 21,291,250
148.1 | MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment |  |
149 | MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines | 105,041,557 | 201,172,289
150 | MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines | 17,501,216 | 28,860,934
151 | MaintenanceOfLineTransformers (595) Maintenance of Line Transformers | 5,992,409 | 6,252,535
152 | MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems | 19,403,006 | 20,824,927
153 | MaintenanceOfMeters (597) Maintenance of Meters | 2,439,146 | 4,732,521
154 | MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant |  |
155 | DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154) | 176,380,884 | 299,300,103
156 | DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155) | 305,855,533 | 444,037,386
157 | CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES |  |
158 | CustomerAccountsExpensesOperationsAbstract Operation |  |
159 | SupervisionCustomerAccountExpenses (901) Supervision | 2,101,688 | 3,798,599
160 | MeterReadingExpenses (902) Meter Reading Expenses | 25,344,544 | 26,001,347
161 | CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses | 119,409,224 | 85,132,243
162 | UncollectibleAccounts (904) Uncollectible Accounts | 25,995,512 | 20,733,836
163 | MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses | 8,951,322 | 9,512,952
164 | CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163) | 181,802,290 | 145,178,977
165 | CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES |  |
166 | CustomerServiceAndInformationalExpensesOperationAbstract Operation |  |
167 | SupervisionCustomerServiceAndInformationExpenses (907) Supervision |  | 83
168 | CustomerAssistanceExpenses (908) Customer Assistance Expenses | 84,251,658 | 71,709,490
169 | InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses | 6,136 | 7,781
170 | MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses | 695,934 | 1,152,801
171 | CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170) | 84,953,728 | 72,854,593
172 | SalesExpenseAbstract 7. SALES EXPENSES |  |
173 | SalesExpenseOperationAbstract Operation |  |
174 | SupervisionSalesExpense (911) Supervision | 210,622 | 611,014
175 | DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses | 31,389,152 | 34,100,375
176 | AdvertisingExpenses (913) Advertising Expenses | 435,633 | 512,783
177 | MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses | 6,980,747 | 6,039,711
178 | SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177) | 39,016,154 | 41,263,883
179 | AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES |  |
180 | AdministrativeAndGeneralExpensesOperationAbstract Operation |  |
181 | AdministrativeAndGeneralSalaries (920) Administrative and General Salaries | 73,616,201 | 84,775,799
182 | OfficeSuppliesAndExpenses (921) Office Supplies and Expenses | 36,844,628 | 2,906,196
183 | AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit | 5,937,226 | 2,032,136
184 | OutsideServicesEmployed (923) Outside Services Employed | 208,126,047 | 145,036,496
185 | PropertyInsurance (924) Property Insurance | 47,368,255 | 229,558,038
186 | InjuriesAndDamages (925) Injuries and Damages | 25,870,679 | 30,645,116
187 | EmployeePensionsAndBenefits (926) Employee Pensions and Benefits | 50,484,167 | 54,634,235
188 | FranchiseRequirements (927) Franchise Requirements |  |
189 | RegulatoryCommissionExpenses (928) Regulatory Commission Expenses | 8,579,402 | 17,939,177
190 | DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr. | 6,354,593 | 15,524,372
191 | GeneralAdvertisingExpenses (930.1) General Advertising Expenses | 14,533,359 | 17,504,903
192 | MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses | 13,922,442 | 18,104,593
193 | RentsAdministrativeAndGeneralExpense (931) Rents | 5,111,194 | 7,498,843
194 | AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193) | 297,506,965 | 481,778,418
195 | AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance |  |
196 | MaintenanceOfGeneralPlant (935) Maintenance of General Plant | 18,040,787 | 36,135,657
197 | AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196) | 315,547,752 | 517,914,075
198 | OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197) | 4,813,841,889 | 6,802,332,052

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
|  |  |  |  | Actual Demand (MW) |  |  | POWER EXCHANGES | COST/SETTLEMENT OF POWER
Line No. | NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a) | StatisticalClassificationCode Statistical Classification (b) | RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c) | AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d) | AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e) | AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f) | MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g) | MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h) | EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i) | EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j) | DemandChargesOfPurchasedPower Demand Charges ($) (k) | EnergyChargesOfPurchasedPower Energy Charges ($) (l) | OtherChargesOfPurchasedPower Other Charges ($) (m) | SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1 | Albany Renewable Energy, LLC | LU |  |  |  |  | 298,925 |  |  |  | 9,567,541 | 21,260,396 |  | 30,827,937
2 | ASI DG Group A Solar Contracts | (e) OS |  |  |  |  | 64,276 |  |  |  |  | 2,927,152 |  | 2,927,152
3 | Associated Energy Cooperative Inc. | OS |  |  |  |  | 6,310 |  |  |  |  | 193,665 |  | 193,665
4 | Augusta Canal Authority | LU |  |  |  |  | 8,863 |  |  |  |  | 254,309 |  | 254,309
5 | Bird Dog Solar LLC | OS |  |  |  |  | 3,509 |  |  |  |  | 95,765 |  | 95,765
6 | Birdsong Corporation | LU |  |  |  |  | 682 |  |  |  |  | 19,862 |  | 19,862
7 | Bulldog Solar, LLC | LU |  |  |  |  | 120,498 |  |  |  |  | 3,621,254 |  | 3,621,254
8 | CAC Contract | LU |  |  |  |  | 437 |  |  |  |  | 13,209 |  | 13,209
9 | Calpine Energy Services | OS |  |  |  |  |  |  |  |  |  |  |  |
10 | Chatsworth Water Works | LU |  |  |  |  | 819 |  |  |  |  | 23,695 |  | 23,695
11 | City of Jesup | LU |  |  |  |  | 132 |  |  |  |  | 3,768 |  | 3,768
12 | City of Tallahassee, Florida | OS |  |  |  |  | 2,794 |  |  |  |  | 48,603 |  | 48,603
13 | City of Troy, Alabama | OS |  |  |  |  |  |  |  |  |  | 171,708 |  | 171,708
14 | Clayton County | LU |  |  |  |  |  |  |  |  |  |  |  |
15 | Coca Cola | LU |  |  |  |  | 41,544 |  |  |  | 113,379 | 3,725,573 |  | 3,838,952
16 | Constellation Energy | LU |  |  |  |  |  |  |  |  |  | 252,355 |  | 252,355
17 | Conyers Renewable Power LLC | LU |  |  |  |  | 13,836 |  |  |  |  | 1,219,524 |  | 1,219,524
18 | Dominion Energy | OS |  |  |  |  | 2,585 |  |  |  |  | 75,103 |  | 75,103
19 | Double Run Solar | OS |  |  |  |  |  |  |  |  |  | 11,308,598 |  | 11,308,598
20 | Dublin Solar I LLC | OS |  |  |  |  | 5,012 |  |  |  |  | 426,049 |  | 426,049
21 | Duke Energy Carolinas, LLC | OS |  |  |  |  | 31,033 |  |  |  |  | 913,180 |  | 913,180
22 | Duke Energy Florida LLC | LU |  |  |  |  | 13,315 |  |  |  |  | 364,853 |  | 364,853
23 | Eagle Energy Partners I, L.P. | OS |  |  |  |  | 15,542 |  |  |  |  | 319,451 |  | 319,451
24 | Effingham County Power, LLC - PPA | OS |  |  |  |  |  |  |  |  |  |  |  |
25 | Endure Energy, LLC | OS |  |  |  |  |  |  |  |  |  |  |  |
26 | Enterprise Mill, LLC | LU |  |  |  |  | 94 |  |  |  |  | 2,447 |  | 2,447
27 | Exelon Generation Company, LLC | OS |  |  |  |  | 6,259 |  |  |  |  | 191,247 |  | 191,247
28 | Florida Power & Light Company | OS |  |  |  |  | 11,083 |  |  |  |  | 476,453 |  | 476,453
29 | Graphic Packaging International | OS |  |  |  |  | 4,075 |  |  |  |  | 117,851 |  | 117,851
30 | (a) Green Energy | OS |  |  |  |  | 590,154 |  |  |  |  | 41,945,502 |  | 41,945,502
31 | Green Power Solutions Inc2 | LU |  |  |  |  | 199,100 |  |  |  | 396,241 | 18,709,664 |  | 19,105,905
32 | GRP LLC | OS |  |  |  |  | 747,414 |  |  |  |  | 69,703,834 |  | 69,703,834
33 | Hecate Energy Old Midville Rd, LLC | LU |  |  |  |  | 39,802 |  |  |  |  | 2,663,130 |  | 2,663,130
34 | Hercules | LU |  |  |  |  |  |  |  |  |  |  |  |
35 | Hickory Park Solar LLC | LU |  |  |  |  | 430,196 |  |  |  |  | 822,298 |  | 822,298
36 | Hobnail Solar, LLC | LU |  |  |  |  | 1,780 |  |  |  |  | 43,527 |  | 43,527
37 | HSH Pembroke LLC | LU |  |  |  |  | 1,632 |  |  |  |  | 202,709 |  | 202,709
38 | IKEA Atlanta | LU |  |  |  |  | 72 |  |  |  |  | 1,887 |  | 1,887
39 | IKEA Savannah | LU |  |  |  |  | 764 |  |  |  |  | 21,438 |  | 21,438
40 | International Paper Flint River | LU |  |  |  |  | 144,030 |  |  |  | 4,514,393 | 9,673,297 |  | 14,187,690
41 | International Paper Port Wentworth | LU |  |  |  |  | 173,038 |  |  |  | 3,838,635 | 11,685,942 |  | 15,524,577
42 | International Paper Qualified Facilities (QF) | OS |  |  |  |  | 2,000 |  |  |  |  | 74,207 |  | 74,207
43 | Invenergy | LU |  |  |  |  | 336,921 |  |  |  | 105,436 | 7,658,067 |  | 7,763,503
44 | Jacksonville Electric Authority | OS |  |  |  |  |  |  |  |  |  | 859 |  | 859
45 | KGen Sandersville LLC | OS |  |  |  |  |  |  |  |  |  | 7,453 |  | 7,453
46 | Louisville Gas & Electric | OS |  |  |  |  | 4,020 |  |  |  |  | 148,105 |  | 148,105
47 | Mackinaw Power LLC | LU |  |  |  |  | 290,449 |  |  |  | 28,321,913 | 3,616,011 |  | 31,937,924
48 | Macquarie Energy, LLC | OS |  |  |  |  | 26,257 |  |  |  |  | 1,172,854 |  | 1,172,854
49 | MARTA | LU |  |  |  |  |  |  |  |  |  |  |  |
50 | MAS Georgia LFG LLC2 | LU |  |  |  |  | 141,261 |  |  |  | 351,186 | 12,669,502 |  | 13,020,688
51 | MCLB Albany (NAVFEC) | LU |  |  |  |  | 22,662 |  |  |  |  | 623,915 |  | 623,915
52 | MEAG PSSA | OS |  |  |  |  | 283,627 |  |  |  |  | 2,861,672 |  | 2,861,672
53 | Mercuria Energy America, Inc | LU |  |  |  |  | 24,175 |  |  |  | 100,675 | 910,376 |  | 1,011,051
54 | Mid Georgia Cogen LP | OS |  |  |  |  | 146,547 |  |  |  | 2,705,208 | 6,540,121 |  | 9,245,329
55 | Midwest Independent Trans System | OS |  |  |  |  | 18,918 |  |  |  |  | 710,342 |  | 710,342
56 | Morgan Stanley Capital Group, Inc. | OS |  |  |  |  | 9,771 |  |  |  |  | 219,263 |  | 219,263
57 | MPC Generating, LLC | OS |  |  |  |  |  |  |  |  |  |  |  |
58 | Municipal Electric Authority Of Georgia | LU |  |  |  |  | 212,022 |  |  |  | 2,892,000 | 1,457,125 |  | 4,349,125
59 | NANTR-OATT-FERC-AttK-Ntwk-Oth | OS |  |  |  |  |  |  |  |  |  |  |  |
60 | NextEra Gulf | OS |  |  |  |  |  |  |  |  |  |  |  |
61 | NextEra Solar | OS |  |  |  |  | 1,842,667 |  |  |  | 264,789 | 55,366,985 |  | 55,631,774
62 | North Carolina EMC | OS |  |  |  |  | 1,239 |  |  |  |  | 28,243 |  | 28,243
63 | North Carolina Municipal Power Agency #1 | OS |  |  |  |  | 190 |  |  |  |  |  |  |
64 | NTE Carolinas | SF |  |  |  |  | 577 |  |  |  |  | 18,136 |  | 18,136
65 | Oglethorpe Power Corporation | LU |  |  |  |  | 10,630 |  |  |  |  | 102,863 |  | 102,863
66 | Origis Energy | LU |  |  |  |  | 522,432 |  |  |  |  | 16,127,912 |  | 16,127,912
67 | Orlando Utilities Commission | OS |  |  |  |  | 84 |  |  |  |  | 2,274 |  | 2,274
68 | Packaging Corporation of America | LU |  |  |  |  | 3,292 |  |  |  |  | 101,577 |  | 101,577
69 | Piedmont Green Power | LU |  |  |  |  | 390,207 |  |  |  | 15,726,450 | 14,081,151 |  | 29,807,601
70 | PJM Interconnection | OS |  |  |  |  | 2,901 |  |  |  |  | 62,891 |  | 62,891
71 | Porsche Cars North America Inc | LU |  |  |  |  | 44 |  |  |  |  | 990 |  | 990
72 | PowerSouth Electric Membership Co. | OS |  |  |  |  |  |  |  |  |  |  |  |
73 | Rainbow Energy Marketing Corporation | OS |  |  |  |  | 22,495 |  |  |  | 2,677 | 1,886,388 |  | 1,889,065
74 | Rayonier Inc | LU |  |  |  |  | 155 |  |  |  |  | 4,370 |  | 4,370
75 | Richland Solar Center LLC | LU |  |  |  |  | 33,629 |  |  |  | 4,250 | 1,860,885 |  | 1,865,135
76 | Rincon Solar I, LLC | LU |  |  |  |  | 28,347 |  |  |  |  | 2,211,387 |  | 2,211,387
77 | Santa Rosa | OS |  |  |  |  |  |  |  |  |  |  |  |
78 | Simon Solar Farm | LU |  |  |  |  | 48,565 |  |  |  |  | 5,938,495 |  | 5,938,495
79 | Solar Design & Development LLC | OS |  |  |  |  | 1,095 |  |  |  |  | 110,376 |  | 110,376
80 | Solar Glynn, LLC | LU |  |  |  |  | 25,813 |  |  |  |  | 1,533,595 |  | 1,533,595
81 | Sonny Solar, LLC | LU |  |  |  |  | 48,893 |  |  |  |  | 1,456,283 |  | 1,456,283
82 | South Carolina Public Service Authority | OS |  |  |  |  | 2,618 |  |  |  |  | 70,797 |  | 70,797
83 | South Mississippi Electric Power Association | OS |  |  |  |  |  |  |  |  |  |  |  |
84 | (b) Southern Company Services | OS |  |  |  |  | 16,918,776 |  | 17,776,641 | 17,767,633 | 16,026,983 | 537,353,993 |  | 553,380,976
85 | Southern Company Transmission | OS |  |  |  |  |  |  |  |  |  | 13,155 |  | 13,155
86 | (c) Southern Electric Generating Co | OS |  |  |  |  | 778,235 |  |  |  | 10,782,295 | 104,320,145 |  | 115,102,440
87 | (d) Southern Power Company | LU |  |  |  |  | 3,242,724 |  |  |  | 89,801,467 | 53,441,689 |  | 143,243,156
88 | Southwest Power Pool, Inc | OS |  |  |  |  |  |  |  |  |  |  |  |
89 | Star Thread - Barnett Shoals Inc | LU |  |  |  |  | 7,448 |  |  |  |  | 201,999 |  | 201,999
90 | Sustaining Power Solutions LLC | LU |  |  |  |  | 710,979 |  |  |  |  | 45,915,024 |  | 45,915,024
91 | Tampa Electric Company | OS |  |  |  |  | 10,842 |  |  |  |  | 299,144 |  | 299,144
92 | Tenaska Heard County Georgia | LU |  |  |  |  | 237,215 |  |  |  | 43,659,000 | 4,008,619 |  | 47,667,619
93 | Tennessee Valley Authority | OS |  |  |  |  | 138,903 |  |  |  |  | 4,145,346 |  | 4,145,346
94 | The Energy Authority | OS |  |  |  |  | 14,439 |  |  |  |  | 410,837 |  | 410,837
95 | Verizon Communications | OS |  |  |  |  | 47 |  |  |  |  | 1,253 |  | 1,253
96 | Walton Electric Membership Corporation | OS |  |  |  |  | 3,652 |  |  |  |  | 56,467 |  | 56,467
97 | Washington County Pwr | OS |  |  |  |  | 42,884 |  |  |  | 11,223,785 | 578,708 |  | 11,802,493
98 | Westar Energy, Inc. | OS |  |  |  |  |  |  |  |  | 0 | 0 |  |
99 | WM Renewable Energy, LLC | OS |  |  |  |  | 46,841 |  |  |  | 125,655 | 4,201,216 |  | 4,326,871
15 | TOTAL |  |  |  |  |  | 29,637,093 |  | 17,776,641 | 17,767,633 | 240,523,958 | 1,073,820,571 |  | 1,314,344,529

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Renewable programs are related to Renewable Energy Development Initiative Utility Scale Requests for Proposal and Simple Solar programs implementation and administrative costs.
(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Southern Company Services is a subsidiary of Southern Company.
(c) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Southern Electric Generating Company is 50% owned by each of Georgia Power and Alabama Power. Prior year amounts were included in totals reported for Southern Company Services.
(d) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Southern Power Company is a subsidiary of Southern Company.
(e) Concept: StatisticalClassificationCode
OS-Unless indicated by FERC Rate Schedule Number, these are market-based purchases of non-firm energy from power marketing companies that have applications on file with the FERC.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c). In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Report in column (i) and (j) the total megawatthours received and delivered. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. Footnote entries and provide explanations following all required data.
|  |  |  |  |  |  |  |  | TRANSFER OF ENERGY | REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No. | PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a) | TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) | TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) | StatisticalClassificationCode Statistical Classification (d) | RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e) | TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f) | TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g) | BillingDemand Billing Demand (MW) (h) | TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i) | TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j) | Demand Charges ($) (k) | Energy Charges ($) (l) | Other Charges ($) (m) | RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n)
1 | Southeastern Power Administration | Southeastern Power Administration | Southeastern Power Administration Preference Customers | FNO | (q) 415 | N/A | N/A | 379 | (x) 619,852 | (ab) 606,218 | (ag) 12,376,892 | 1,007 | (ai) 31,755 | 12,407,640
2 | Tennessee Valley Authority | Tennessee Valley Authority | Distributors of Tennessee Valley Authority | FNO | (r) 160 | N/A | N/A | (u) 1,517 | 693,488 | 678,231 | 3,066,269 | 0 | 30,455 | 3,096,724
3 | PowerSouth Energy Cooperative | PowerSouth Energy Cooperative | PowerSouth Energy Cooperative | FNO | 225 | N/A | N/A | 712 | 3,927,409 | 3,841,005 | 10,543,757 | 0 | 96,691 | 10,640,448
4 | Alabama Municipal Electric Authority | Alabama Municipal Electric Authority | Alabama Municipal Electric Authority | FNO | 474 | N/A | N/A | 470 | 3,282,274 | 3,210,065 | 989,885 | 0 | 15,545 | 1,005,430
5 | Cooperative Energy | South Mississippi Electric Power Association | South Mississippi Electric Power Association | FNO | 496 | N/A | N/A | 641 | 3,426,912 | 3,351,519 | 2,515,672 | 0 | 27,848 | 2,543,520
6 | City of Troy | City of Troy | City of Troy | FNO | 504 | N/A | N/A | 61 | 452,231 | 442,283 | 127,576 | 0 | 854 | 128,430
7 | City of Evergreen | City of Evergreen | City of Evergreen | FNO | 542 | N/A | N/A | 10 | 56,312 | 55,073 | 253,536 | 0 | 2,661 | 256,197
8 | City of Hartford | City of Hartford | City of Hartford | FNO | 543 | N/A | N/A | 3 | 25,473 | 24,912 | 109,700 | 0 | 1,571 | 111,271
9 | City of Robertsdale | City of Robertsdale | City of Robertsdale | FNO | 544 | N/A | N/A | 13 | 89,544 | 87,574 | 339,593 | 0 | 4,097 | 343,690
10 | FPL2014 - Exxon & Blackjack | Florida Power & Light | Florida Power & Light | FNO | 717 | N/A | N/A | 11 | 85,066 | 83,195 | 254,919 | 0 | 4,062 | 258,981
11 | EXELON GENERATION COMPANY, LLC | EXELON GENERATION COMPANY, LLC | GTC | (d) LFP | TSA | HILLABEE | GTC | 210 | (y) 1,568,339 | (ac) 1,534,008 | 6,179,660 | 0 | 89,793 | 6,269,453
12 | FLORIDA POWER & LIGHT COMPANY | EXELON GENERATION COMPANY, LLC | GTC | (e) LFP | TSA | DANIEL | FPLNW | 489 | 125,336 | 122,544 | 303,636 | 0 | 3,248 | 306,884
13 | FLORIDA POWER & LIGHT COMPANY | EXELON GENERATION COMPANY, LLC | GTC | (f) LFP | TSA | SCHERER | FPLNW | 215 | 516,208 | 504,725 | 133,501 | 0 | 28,994 | 162,495
14 | FLORIDA POWER & LIGHT COMPANY | EXELON GENERATION COMPANY, LLC | GTC | (g) LFP | TSA | SOCOGEN | FPLNW | 124 | 1,000,828 | 978,200 | 76,996 | 0 | 46,991 | 123,987
15 | FLORIDA POWER & LIGHT COMPANY | FLORIDA POWER & LIGHT COMPANY | FPLNW | (h) LFP | TSA | SOCOGEN | FPLNW | 65 | 0 | 0 | 40,361 | 0 | 46,991 | 87,352
16 | JACKSONVILLE ELECTRIC AUTHORITY | JACKSONVILLE ELECTRIC AUTHORITY | JEA | (i) LFP | TSA | VOGTLE | JEA | 42 | 39,419 | 38,936 | 1,878,373 | 0 | 3,383 | 1,881,756
17 | JACKSONVILLE ELECTRIC AUTHORITY | JACKSONVILLE ELECTRIC AUTHORITY | JEA | (j) LFP | TSA | VOGTLE | JEA | 61 | 75,310 | 73,775 | 2,728,113 | 0 | 6,410 | 2,734,523
18 | JACKSONVILLE ELECTRIC AUTHORITY | JACKSONVILLE ELECTRIC AUTHORITY | JEA | (k) LFP | TSA | VOGTLE | JEA | 103 | 1,316,463 | 1,298,713 | 4,606,485 | 0 | 115,519 | 4,722,004
19 | MERCURIA ENERGY AMERICA, LLC. | MERCURIA ENERGY AMERICA, LLC. | GTC | (l) LFP | TSA | LINDSAY HILL | GTC | 220 | 1,288,877 | 1,262,299 | 6,029,573 | 0 | 68,729 | 6,098,302
20 | NORTH CAROLINA ELECTRIC MEMBERSHIP CORPORATION | North Carolina Electric Membership Corporation | DUK | (m) LFP | TSA | DAHLBERG | DUK | 44 | 15,674 | 15,674 | 1,998,211 | 0 | 1,465 | 1,999,676
21 | POWERSOUTH ENERGY COOPERATIVE | POWERSOUTH ENERGY COOPERATIVE | FPLNW | (n) LFP | TSA | MILLER | FPLNW | 142 | 583,695 | 583,684 | 0 | 0 | 16,936 | 16,936
22 | SEMINOLE ELECTRIC COOPERATIVE INCORPORATED | SEMINOLE ELECTRIC COOPERATIVE INCORPORATED | FPL | (o) LFP | TSA | DANIEL | FPL | 50 | 96,804 | 94,644 | 498,038 | 0 | 4,430 | 502,468
23 | SEMINOLE ELECTRIC COOPERATIVE INCORPORATED | SEMINOLE ELECTRIC COOPERATIVE INCORPORATED | FPL | (p) LFP | TSA | DANIEL | FPL | 100 | 405,122 | 395,936 | 2,390,584 | 0 | 18,791 | 2,409,375
24 | (a) VARIOUS Non Firm Customers | (c) VARIOUS Non Firm Customers | VARIOUS | NF | TSA | (s) VARIOUS | (t) VARIOUS | (v) 0 | (z) 246,890 | (ad) 243,051 | 1,491,786 | 0 | 13,214 | 1,505,000
25 | (b) VARIOUS Short Term Firm Customers | VARIOUS Short Term Firm Customers | VARIOUS | SFP | TSA | VARIOUS | VARIOUS | (w) 0 | (aa) 7,941,753 | (ae) 7,830,065 | 43,798,479 | 0 | 519,826 | 44,318,305
26 | VARIOUS Tariff Customers | VARIOUS Tariff Customers | VARIOUS | AD | TSA | VARIOUS | VARIOUS | 0 | 0 | 0 | 0 | 0 | (aj) 1,390,894 | 1,390,894
27 | VARIOUS Tariff Customers | VARIOUS Tariff Customers | VARIOUS | OS | TSA | VARIOUS | VARIOUS | 0 | 3,665,906 | (af) 3,630,165 | (ah) 10,270,522 | 0 | 200,975 | 10,471,497
35 | TOTAL |  |  |  |  |  |  | 5,682 | 31,545,185 | 30,986,494 | 113,002,117 | 1,007 | 2,792,128 | 115,793,238

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: PaymentByCompanyOrPublicAuthority
Various Non-Firm Point-to-Point Transmission Service customers under the Southern Companies' Open Access Transmission Tariff.
(b) Concept: PaymentByCompanyOrPublicAuthority
Various Short-Term Firm Point-to-Point Transmission Service customers under the Tariff
(c) Concept: TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Various entities pursuant to the terms and conditions of the Tariff
(d) Concept: StatisticalClassificationCode
Termination Date: June 1, 2025
(e) Concept: StatisticalClassificationCode
Termination Date: January 1, 2036
(f) Concept: StatisticalClassificationCode
Termination Date: January 1, 2036
(g) Concept: StatisticalClassificationCode
Termination Date: January 1, 2036
(h) Concept: StatisticalClassificationCode
Termination Date: January 1, 2036
(i) Concept: StatisticalClassificationCode
Termination Date: June 1, 2025
(j) Concept: StatisticalClassificationCode
Termination Date: June 1, 2025
(k) Concept: StatisticalClassificationCode
Termination Date: June 1, 2025
(l) Concept: StatisticalClassificationCode
Termination Date: May 1, 2027
(m) Concept: StatisticalClassificationCode
Termination Date: May 1, 2027
(n) Concept: StatisticalClassificationCode
Termination Date: January 1, 2029
(o) Concept: StatisticalClassificationCode
Termination Date: June 1, 2024
(p) Concept: StatisticalClassificationCode
Termination Date: January 1, 2024
(q) Concept: RateScheduleTariffNumber
Schedule Page: _____ Line Nos. 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 Column: i
(r) Concept: RateScheduleTariffNumber
Line Nos. 2 through 22 Column: e FERC Electric Tariff Fourth Revised Volume No. 5, the "Tariff."
(s) Concept: TransmissionPointOfReceipt
Various points of receipt.
(t) Concept: TransmissionPointOfDelivery
Various points of delivery.
(u) Concept: BillingDemand
The billing demand is based on a rolling 12 month average of the Transmission Customer's load under the Tariff coincident with the Transmission Provider's monthly transmission peak load. The demand reported in column h is the most recent 12 month average load for the quarter.
(v) Concept: BillingDemand
Various - Total billing demand varies based on the duration of service (e.g. hourly, daily, weekly, or monthly.
(w) Concept: BillingDemand
Various - Total billing demand varies based on the duration of service (e.g. daily, weekly, or monthly).
(x) Concept: TransmissionOfElectricityForOthersEnergyReceived
Total MWH received by the Southern Company electric operating companies for Network Integration Transmission Service.
(y) Concept: TransmissionOfElectricityForOthersEnergyReceived
The billing demand is based on a rolling 12 month average of the Transmission Customer's load under the Tariff coincident with the Transmission Provider's monthly transmission peak load. The demand reported in column h is the most recent 12 month average load for the quarter.
(z) Concept: TransmissionOfElectricityForOthersEnergyReceived
Total MWH received by Southern Company electric operating companies for Non-Firm Point-to-Point Transmission Service.
(aa) Concept: TransmissionOfElectricityForOthersEnergyReceived
Total MWH received by Southern Company electric operating companies for Short-Term Firm Point-to-Point Transmission Service.
(ab) Concept: TransmissionOfElectricityForOthersEnergyDelivered
Total MWH delivered by the Southern Company electric operating companies for Network Integration Transmission Service.
(ac) Concept: TransmissionOfElectricityForOthersEnergyDelivered
Total MWH delivered by Southern Company electric operating companies for Long-Term Firm Point-to-Point Transmission Service .
(ad) Concept: TransmissionOfElectricityForOthersEnergyDelivered
Total MWH delivered by the Southern Company electric operating companies for Non-Firm Point-to-Point Transmission Service.
(ae) Concept: TransmissionOfElectricityForOthersEnergyDelivered
Total MWH delievered by Southern Company electric operating companies for Short-Term Firm Point-to-Point Transmission Service.
(af) Concept: TransmissionOfElectricityForOthersEnergyDelivered
OS: OS consists of recallable contracts. Billing demand is not reported because these types of contracts are excluded from the tariff rate load calculation. MWH Delivered and Received
(ag) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers
Amount of charges allocated to the respondent.
(ah) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers
OS: OS consists of recallable contracts. Billing demand is not reported because these types of contracts are excluded from the tariff rate load calculation. Demand and Other Dollars
(ai) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
The Southern Company electric operating companies' Charge for Recovery of the FERC Annual and Attachment K Charges.
(aj) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Various Long-Term Firm, Conditional Long-Term Firm and Network Integration Transmission Service Customers that purchased service during January 2022 through December 2022, and will receive OATT Tariff True-Up refunds.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No. | Payment Received by (Transmission Owner Name) (a) | Statistical Classification (b) | FERC Rate Schedule or Tariff Number (c) | Total Revenue by Rate Schedule or Tariff (d) | Total Revenue (e)
1 |  |  |  |  |
2 |  |  |  |  |
3 |  |  |  |  |
4 |  |  |  |  |
5 |  |  |  |  |
6 |  |  |  |  |
7 |  |  |  |  |
8 |  |  |  |  |
9 |  |  |  |  |
10 |  |  |  |  |
11 |  |  |  |  |
12 |  |  |  |  |
13 |  |  |  |  |
14 |  |  |  |  |
15 |  |  |  |  |
16 |  |  |  |  |
17 |  |  |  |  |
18 |  |  |  |  |
19 |  |  |  |  |
20 |  |  |  |  |
21 |  |  |  |  |
22 |  |  |  |  |
23 |  |  |  |  |
24 |  |  |  |  |
25 |  |  |  |  |
26 |  |  |  |  |
27 |  |  |  |  |
28 |  |  |  |  |
29 |  |  |  |  |
30 |  |  |  |  |
31 |  |  |  |  |
32 |  |  |  |  |
33 |  |  |  |  |
34 |  |  |  |  |
35 |  |  |  |  |
36 |  |  |  |  |
37 |  |  |  |  |
38 |  |  |  |  |
39 |  |  |  |  |
40 |  |  |  |  |
41 |  |  |  |  |
42 |  |  |  |  |
43 |  |  |  |  |
44 |  |  |  |  |
45 |  |  |  |  |
46 |  |  |  |  |
47 |  |  |  |  |
48 |  |  |  |  |
49 |  |  |  |  |
40 | TOTAL |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
|  |  | TRANSFER OF ENERGY | EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No. | NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a) | StatisticalClassificationCode Statistical Classification (b) | TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c) | TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d) | DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e) | EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f) | OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g) | ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1 | Duke Energy | OS | 16,962 |  |  |  | 53,500 | 53,500
2 | Midwest Independent Trans System | OS | 20,912 |  |  |  | 23,519 | 23,519
3 | Southern Power (EMC 11) | OS | 716,068 |  |  |  | 353,820 | 353,820
4 | Southern Company Services (Self-Use) | OS | 1,151,398 |  |  |  | 7,084,625 | 7,084,625
5 | Tennessee Valley Authority | OS | 21,356 |  |  |  | 512,947 | 512,947
6 | Floriday Power & Light Company | OS | 1,014 |  |  |  | 8,289 | 8,289
7 | Municipal Electric Authority of Ga (MEAG) | OS |  |  |  |  | 377 | 377
8 | Dominion Energy | OS |  |  |  |  | 1,319 | 1,319
9 | PJM | OS | 87 |  |  |  |  |
10 | SC Public Service Authority | OS |  |  |  |  | 507 | 507
| TOTAL |  | 1,927,797 |  |  |  | 8,038,903 | 8,038,903

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No. | Description (a) | Amount (b)
1 | IndustryAssociationDues Industry Association Dues | 1,081,100
2 | NuclearPowerResearchExpenses Nuclear Power Research Expenses |
3 | OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses | 4,501,019
4 | PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities | 46,891
5 | OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000 |
6 | Directors' Fees and Expenses | 1,723,595
7 | Substance Abuse Testing | 118,670
8 | Community Development | 1,156,578
9 | Agent Fees | 4,465,158
10 | DOE Loan Guarantee Fees and Compliance Cost | 705,593
11 | Miscellaneous General Expenses | 212,506
12 | COVID-19 Costs | 88,668
46 | MiscellaneousGeneralExpenses TOTAL | 13,922,442

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
| A. Summary of Depreciation and Amortization Charges
Line No. | FunctionalClassificationAxis Functional Classification (a) | DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b) | DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c) | AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d) | AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e) | DepreciationAndAmortization Total (f)
1 | Intangible Plant |  |  | 63,664,133 |  | 63,664,133
2 | Steam Production Plant | 390,177,138 | 21,596,778 |  |  | 411,773,916
3 | Nuclear Production Plant | 103,825,923 | 5,771,165 |  |  | 109,597,088
4 | Hydraulic Production Plant-Conventional | 18,268,289 | 267,057 |  |  | 18,535,346
5 | Hydraulic Production Plant-Pumped Storage | 8,847,568 |  |  |  | 8,847,568
6 | Other Production Plant | 169,860,677 | 1,831,953 |  |  | 171,692,630
7 | Transmission Plant | 184,781,424 | 35,292 |  |  | 184,746,132
8 | Distribution Plant | 416,801,980 | 11,795 |  |  | 416,790,185
9 | Regional Transmission and Market Operation |  |  |  |  |
10 | General Plant | 42,891,798 | 204,182 |  |  | 42,687,616
11 | Common Plant-Electric |  |  |  |  |
12 | TOTAL | (a) 1,335,454,797 | 29,215,684 | 63,664,133 |  | 1,428,334,614

B. Basis for Amortization Charges

| C. Factors Used in Estimating Depreciation Charges
Line No. | AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a) | DepreciablePlantBase Depreciable Plant Base (in Thousands) (b) | UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c) | UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d) | UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e) | MortalityCurveType Mortality Curve Type (f) | UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12 | Steam | 7,807.223 | 70 years | 20 | 7.24 | VARIOUS | 9 years, 5 months
13 | Nuclear | 7,594.11 | 69 years | 25 | 1.8 | VARIOUS | 38 years, 9 months
14 | Hydraulic | 926.179 | 90 years | 30 | 3.08 | VARIOUS | 20 years, 4 months
15 | Other | 3,797.624 | 42 years | 4 | 5.12 | VARIOUS | 25 years, 6 months
16 | Transmission |  |  |  |  |  |
17 | 350 | 452.898 | 120 years | 0 | 0.52 | S6 | 111 years, 11 months
18 | 352 | 301.395 | 100 years | 30 | 1.34 | R2 | 88 years, 4 months
19 | 353 | 3,079.178 | 53 years | 30 | 2.57 | L0.5 | 44 years, 6 months
20 | 354 | 1,246.397 | 68 years | 30 | 2.04 | R2 | 52 years, 10 months
21 | 355 | 867.45 | 54 years | 30 | 2.52 | R0.5 | 45 years
22 | 356 | 1,919.817 | 50 years | 30 | 2.85 | R3 | 35 years, 9 months
23 | 357 | 11.852 | 80 years | 30 | 1.73 | R5 | 63 years, 3 months
24 | 358 | 24.454 | 55 years | 30 | 2.48 | R2 | 45 years, 9 months
25 | 359 | 16.01 | 70 years | 30 | 1.88 | SQ | 66 years
26 | Transmission Total | 7,919.451 | 72 years |  | 2.44 |  | 61 years, 6 months
27 | Distribution |  |  |  |  |  |
28 | 360 | 262.472 | 100 years | 0 | 1 | S6 | 94 years
29 | 361 | 332.431 | 85 years | 25 | 1.45 | R1.5 | 75 years, 1 month
30 | 362 | 2,098.748 | 47 years | 25 | 2.6 | R0.5 | 39 years, 5 months
31 | 364 | 1,480.997 | 47 years | 25 | 2.59 | L0 | 38 years
32 | 365 | 1,797.29 | 40 years | 25 | 3.04 | L0 | 32 years, 5 months
33 | 366 | 621.303 | 80 years | 25 | 1.51 | S6 | 60 years, 9 months
34 | 367 | 2,965.199 | 51 years | 25 | 2.39 | R0.5 | 41 years, 7 months
35 | 368 | 2,075.903 | 38 years | 25 | 3.16 | R0.5 | 28 years, 2 months
36 | 369 | 1,262.609 | 51 years | 25 | 2.35 | R1 | 37 years, 4 months
37 | 370 | 561.174 | 18 years | 25 | 6.6 | R0.5 | 12 years, 7 months
38 | 371 | 20.397 | 10 years | 0 | 9.64 | SQ | 7 years, 8 months
39 | 372 | 0.798 | 10 years | 0 | 0 | SQ |
40 | 373 | 1,101.106 | 23 years | 25 | 5.21 | R0.5 | 16 years, 11 months
41 | Distribution Total | 14,580.427 | 49 years |  | 2.9 |  | 37 years, 3 months
42 | General |  |  |  |  |  |
43 | 390 | 807.005 | 65 years | 0 | 1.28 | R0.5 | 55 years, 10 months
44 | 392 | 426.849 | 8 years | 20 | 4.06 | VARIOUS | 5 years, 7 months
45 | 396 | 42.3 | 7 years | 20 | 8.02 | L0 | 5 years, 3 months
46 | 397 | 537.447 | 20 years | 0 | 2.72 | L0 | 20 years, 3 months
47 | General Total | 1,813.601 | 25 years |  | 2.65 |  | 21 years, 9 months

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
1) The depreciable base is calculated as an average of beginning and ending plant in service balances. 2) The average remaining service life is presented as of the measurement date used in the study to compute the depreciation rates used in the current year.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
|  |  |  |  |  | EXPENSES INCURRED DURING YEAR | AMORTIZED DURING YEAR
|  |  |  |  |  | CURRENTLY CHARGED TO |  |  |  |
Line No. | RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a) | RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b) | RegulatoryExpensesOfUtility Expenses of Utility (c) | RegulatoryCommissionExpensesAmount Total Expenses for Current Year (b) + (c) (d) | OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e) | NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f) | AccountNumberRegulatoryCommissionExpensesCharged Account No. (g) | RegulatoryComissionExpensesIncurredAndCharged Amount (h) | RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i) | DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j) | DeferredRegulatoryCommissionExpensesAmortized Amount (k) | OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1 | VOGTLE 3 & 4 CONSTRUCTION MONITORING - DOCKET NO. 29849 |  | 10,936,340 | 10,936,340 |  | ELECTRIC | 107 | 10,936,340 |  |  |  |
2 | WALLACE DAM HYDRO RE-LICENSING DKT P-2413 |  | 5,950 | 5,950 |  | ELECTRIC | 928 | 5,950 |  |  |  |
3 | FUEL COST RECOVERY - DOCKET NO. 22403 and 44902 |  | 565,270 | 565,270 |  | ELECTRIC | 928 | 565,270 |  |  |  |
4 | RENEWABLES AND GREEN ENERGY - DOCKET NO. 43107,43085, 43814, and 43985 |  | 8,415 | 8,415 |  | ELECTRIC | 928 | 8,415 |  |  |  |
5 | INTEGRATED RESOURCE PLAN - DOCKET NOS. 42641, 42310, 45084, 44160, and 55378 |  | 1,202,199 | 1,202,199 |  | ELECTRIC | 928 | 1,202,199 |  |  |  |
6 | DEMAND SIDE MANAGEMENT CERTIFICATION - DOCKET NOS. 42311, 43040, and 44161 |  | 128,858 | 128,858 |  | ELECTRIC | 928 | 128,858 |  |  |  |
7 | ALTERNATIVE RATE PLAN - DOCKET NOs. 36989, 42516, 43083, and 44280 |  | 1,075,138 | 1,075,138 |  | ELECTRIC | 928 | 1,075,138 |  |  |  |
8 | WEST FRASER & STANDARD CONCRETE PETIT - DOCKET NOS. 43689, 43690, and 43688 |  | 1,518 | 1,518 |  | ELECTRIC | 928 | 1,518 |  |  |  |
9 | FINANCING AUTHORITY APPLICATION - DOCKET NO. 44054 |  | 26,809 | 26,809 |  | ELECTRIC | 928 | 26,809 |  |  |  |
10 | SAWNEE EMC v. GPC - DOCKET NO. 43899 |  | 153,286 | 153,286 |  | ELECTRIC | 928 | 153,286 |  |  |  |
11 | ROBINS AIR FORCE - DOCKET NO. 40161 |  | 279 | 279 |  | ELECTRIC | 107 | 279 |  |  |  |
12 | ALL SOURCE RFP DOCKET 55268 |  | 67,706 | 67,706 |  | ELECTRIC | 928 | 67,706 |  |  |  |
13 | DOCKET ITEMS UNDER $25,000 (7 ITEMS): (APPLICATIONS FEES, LEGAL AND PROFESSIONAL SERVICES) |  | 8,367 | 8,367 |  | ELECTRIC | 928 | 8,367 |  |  |  |
14 |  |  |  |  |  | 0 | 0 |  |  |  |  |
46 | TOTAL |  | 14,180,135 | 14,180,135 |  |  |  | 14,180,135 |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
|  |  |  |  | AMOUNTS CHARGED IN CURRENT YEAR |
Line No. | ResearchDevelopmentAndDemonstrationClassification Classification (a) | ResearchDevelopmentAndDemonstrationDescription Description (b) | ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c) | ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d) | AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e) | ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f) | ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1 | A. ELECTRIC UTILITY R,D&D PERFORMED INTERNALLY |  |  |  |  |  |
2 | (1) GENERATION |  |  |  |  |  |
3 | b. Fossil-fuel steam | Advanced Power Plant 506 | 1,149,766 |  | 506 | 960,496 |
4 |  | Advanced Power Plant 549 |  |  | 549 | 189,270 |
5 | d. Nuclear | Advanced Nuclear | 3,482,694 |  | 524 | 3,482,694 |
6 | e. Unconventional Generation | Renewable, Storage, Distributed Generation | 838,760 |  | 930.2 | 246,764 |
7 |  |  |  |  | 549 | 592,174 |
8 | (2) TRANSMISSION |  |  |  | 566 | 178 |
9 | a. Overhead | Power Delivery Transmission Research | 1,164,961 |  | 566 | 1,164,961 |
10 | (3) DISTRIBUTION | Power Delivery Distribution Research | 539,393 |  | 588 | 539,393 |
11 | (5) ENVIRONMENTAL | Advanced End Use Technology 930.2 | 3,368,408 |  | 930.2 | 1,539,180 |
12 |  | Advanced Energy Systems 506 |  |  | 506 | 1,829,228 |
13 |  | Environmental Controls Technologies 506 | 496,618 |  | 506 | 463,726 |
14 |  | Environmental Controls Technologies 566 |  |  | 566 | 32,892 |
15 | (6) OTHER | Research Administration 930.2 | 1,614,581 |  | 930.2 | 1,577,504 |
16 |  | Research Administration 566 |  |  | 566 | 24,533 |
17 |  | Research Administration 588 |  |  | 588 | 12,544 |
18 | B. ELECTRIC UTILITY R,D&D PERFORMED EXTERNALLY |  |  |  |  |  |
19 | (1) RESEARCH SUPPORT TO THE ELECTRIC |  |  |  |  |  |
20 | POWER RESEARCH INSTITUTE | Electric Power Research Institute 506 |  | 7,146,753 | 506 | 1,259,638 |
21 |  | Electric Power Research Institute 524 |  |  | 524 | 1,918,096 |
22 |  | Electric Power Research Institute 539 |  |  | 539 | 107,311 |
23 |  | Electric Power Research Institute 549 |  |  | 549 | 961,576 |
24 |  | Electric Power Research Institute 566 |  |  | 566 | 1,668,368 |
25 |  | Electric Power Research Institute 588 |  |  | 588 | 546,807 |
26 |  | Electric Power Research Institute 910 |  |  | 910 | 678,724 |
27 |  | Electric Power Research Institute 555 |  |  | 555 | 6,233 |
28 | LESS COST BILLED TO OTHERS |  |  | 801,671 | 506, 524, 549, 555, 566 | 801,671 |
29 | TOTAL COMPANY COST |  | 12,655,181 | 6,345,082 |  | 19,000,263 |
30 | 0 |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No. | Classification (a) | Direct Payroll Distribution (b) | Allocation of Payroll Charged for Clearing Accounts (c) | Total (d)
1 | SalariesAndWagesElectricAbstract Electric |  |  |
2 | SalariesAndWagesElectricOperationAbstract Operation |  |  |
3 | SalariesAndWagesElectricOperationProduction Production | 88,972,701 |  |
4 | SalariesAndWagesElectricOperationTransmission Transmission | 17,522,408 |  |
5 | SalariesAndWagesElectricOperationRegionalMarket Regional Market |  |  |
6 | SalariesAndWagesElectricOperationDistribution Distribution | 62,092,532 |  |
7 | SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts | 55,433,241 |  |
8 | SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational | 14,647,696 |  |
9 | SalariesAndWagesElectricOperationSales Sales | 25,005,183 |  |
10 | SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General | 77,302,588 |  |
11 | SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10) | 340,976,349 |  |
12 | SalariesAndWagesElectricMaintenanceAbstract Maintenance |  |  |
13 | SalariesAndWagesElectricMaintenanceProduction Production | 27,755,764 |  |
14 | SalariesAndWagesElectricMaintenanceTransmission Transmission | 19,473,966 |  |
15 | SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market |  |  |
16 | SalariesAndWagesElectricMaintenanceDistribution Distribution | 56,099,306 |  |
17 | SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General | 2,438,206 |  |
18 | SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17) | 105,767,242 |  |
19 | SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance |  |  |
20 | SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13) | 116,728,465 |  |
21 | SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14) | 36,996,374 |  |
22 | SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15) |  |  |
23 | SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16) | 118,191,838 |  |
24 | SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7) | 55,433,241 |  |
25 | SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8) | 14,647,696 |  |
26 | SalariesAndWagesElectricSales Sales (Transcribe from line 9) | 25,005,183 |  |
27 | SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17) | 79,740,794 |  |
28 | SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27) | 446,743,591 | 5,830,358 | 452,573,948
29 | SalariesAndWagesGasAbstract Gas |  |  |
30 | SalariesAndWagesGasOperationAbstract Operation |  |  |
31 | SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas |  |  |
32 | SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.) |  |  |
33 | SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply |  |  |
34 | SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing |  |  |
35 | SalariesAndWagesGasOperationTransmission Transmission |  |  |
36 | SalariesAndWagesGasOperationDistribution Distribution |  |  |
37 | SalariesAndWagesGasCustomerAccounts Customer Accounts |  |  |
38 | SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational |  |  |
39 | SalariesAndWagesGasSales Sales |  |  |
40 | SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General |  |  |
41 | SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40) |  |  |
42 | SalariesAndWagesGasMaintenanceAbstract Maintenance |  |  |
43 | SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas |  |  |
44 | SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development) |  |  |
45 | SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply |  |  |
46 | SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing |  |  |
47 | SalariesAndWagesGasMaintenanceTransmission Transmission |  |  |
48 | SalariesAndWagesGasMaintenanceDistribution Distribution |  |  |
49 | SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General |  |  |
50 | SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49) |  |  |
51 | SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance |  |  |
52 | SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43) |  |  |
53 | SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32, |  |  |
54 | SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45) |  |  |
55 | SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru |  |  |
56 | SalariesAndWagesGasTransmission Transmission (Lines 35 and 47) |  |  |
57 | SalariesAndWagesGasDistribution Distribution (Lines 36 and 48) |  |  |
58 | SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37) |  |  |
59 | SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38) |  |  |
60 | SalariesAndWagesGasSales Sales (Line 39) |  |  |
61 | SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49) |  |  |
62 | SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61) |  |  |
63 | SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments |  |  |
64 | SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance |  |  |
65 | SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64) | 446,743,591 | 5,830,358 | 452,573,949
66 | SalariesAndWagesUtilityPlantAbstract Utility Plant |  |  |
67 | SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments) |  |  |
68 | SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant | 327,521,695 | 22,179,180 | 349,700,875
69 | SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant |  |  |
70 | SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote): |  |  |
71 | SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70) | 327,521,695 | 22,179,180 | 349,700,875
72 | SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments) |  |  |
73 | SalariesAndWagesPlantRemovalElectricPlant Electric Plant |  |  |
74 | SalariesAndWagesPlantRemovalGasPlant Gas Plant |  |  |
75 | SalariesAndWagesPlantRemovalOther Other (provide details in footnote): |  |  |
76 | SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75) |  |  |
77 | SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote): |  |  |
78 | SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote): |  |  |
79 | SalariesAndWagesOtherAccountsDescription Accounts Receivable | 23,598,985 | 176,276 | 23,775,261
80 | SalariesAndWagesOtherAccountsDescription Office Building | 1,157,422 |  | 1,157,422
81 | SalariesAndWagesOtherAccountsDescription Printing and Reproduction | 1,171,070 |  | 1,171,070
82 | SalariesAndWagesOtherAccountsDescription Tool Clearing | 116,173 |  | 116,173
83 | SalariesAndWagesOtherAccountsDescription General Shops Expenses | 2,635,031 |  | 2,635,031
84 | SalariesAndWagesOtherAccountsDescription Other Clearing Accounts | 535,839 |  | 535,839
85 | SalariesAndWagesOtherAccountsDescription Jobbing Work in Progress | 1,128,153 |  | 1,128,153
86 | SalariesAndWagesOtherAccountsDescription Other Non-Operating Expenses | 21,102,572 | 2,056,217 | 23,158,789
87 | SalariesAndWagesOtherAccountsDescription All Other General Accounts | 14,379,860 |  | 14,379,860
88 | SalariesAndWagesOtherAccountsDescription |  |  |
89 | SalariesAndWagesOtherAccountsDescription |  |  |
90 | SalariesAndWagesOtherAccountsDescription |  |  |
91 | SalariesAndWagesOtherAccountsDescription |  |  |
92 | SalariesAndWagesOtherAccountsDescription |  |  |
93 | SalariesAndWagesOtherAccountsDescription |  |  |
94 | SalariesAndWagesOtherAccountsDescription |  |  |
95 | SalariesAndWagesOtherAccounts TOTAL Other Accounts | 65,825,105 | 2,232,493 | 68,057,598
96 | SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES | 840,090,391 | 30,242,031 | 870,332,422

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No. | Description of Item(s) (a) | Balance at End of Quarter 1 (b) | Balance at End of Quarter 2 (c) | Balance at End of Quarter 3 (d) | Balance at End of Year (e)
1 | Energy |  |  |  |
2 | Net Purchases (Account 555) | (a) 483,005 | 531,867 | 622,179 | 670,839
2.1 | Net Purchases (Account 555.1) |  |  |  |
3 | Net Sales (Account 447) | 224,159 | 449,245 | 398,958 | 648,050
4 | Transmission Rights | 158,618 | 214,423 | 297,263 | 414,644
5 | Ancillary Services | 80 | 80 | 933 | 1,103
6 | Other Items (list separately) |  |  |  |
7 | Balancing Operating Reserve | 57 | 490 | 1,060 | 2,026
8 | Administrative Fees | 2,213 | 4,185 | 5,649 | 7,240
9 | Miscellaneous | 45 | 81 | 354 | 278
46 | TOTAL | 419,769 | 301,719 | 528,480 | (b) 448,080

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: IsoOrRtoSettlementsEnergyNetPurchasesPurchasedPower
Line Nos. 1-9 Columns: b-e These amounts represent Georgia Power’s portion of the RTO settlement statements received by Southern Company Services. RTO settlement statements received by Southern Company Services include amounts allocated to Alabama Power, Georgia Power, Mississippi Power, and Southern Power Company.
(b) Concept: IsoOrRtoSettlements
The amounts presented agree with settlement statements received and do not include adjustments from other periods that might have been booked.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
|  | Amount Purchased for the Year | Amount Sold for the Year
|  | Usage - Related Billing Determinant | Usage - Related Billing Determinant
Line No. | Type of Ancillary Service (a) | Number of Units (b) | Unit of Measure (c) | Dollar (d) | Number of Units (e) | Unit of Measure (f) | Dollars (g)
1 | Scheduling, System Control and Dispatch | 0 | — | (a) 0 | 109,256 | MW-Months | 8,805,527
2 | Reactive Supply and Voltage | 6,364 | MWhs | 700,000 | 51,399 | MW-Months | 5,653,043
3 | Regulation and Frequency Response | 0 | — | 0 | 20,538 | MW-Months | 992,043
4 | Energy Imbalance | 28,695 | MWhs | 1,136,515 | 16,682 | MWhs | 698,778
5 | Operating Reserve - Spinning | 0 | — | 0 | 15,902 | MW-Months | 1,336,092
6 | Operating Reserve - Supplement | 0 | — | 0 | 15,902 | MW-Months | 1,336,092
7 | Other | (b) 32337 | MWhs | 892,929 | 15,043 | MWhs | 723,479
8 | Total (Lines 1 thru 7) | 67,396 |  | 2,729,444 | 244,722 |  | 19,545,054

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: AncillaryServicesPurchasedAmount
Line No. 1-6 column: d, g The Southern Company electric operating companies (Alabama Power Company, Georgia Power Company, and Mississippi Power Company) collectively are the Transmission Provider under the Open Access Transmission Tariff (OATT) and operate their transmission facilities as a single integrated system. The ancillary services, sales, and purchase amounts associated with transmission service provided under the OATT are the total values for the Southern Company electric operating companies.
(b) Concept: AncillaryServicesPurchasedNumberOfUnits
Line No. 7 column: b,d,e,g Generator Imbalance Service (Schedule 10) offered under the OATT.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No. | Month (a) | Monthly Peak MW - Total (b) | Day of Monthly Peak (c) | Hour of Monthly Peak (d) | Firm Network Service for Self (e) | Firm Network Service for Others (f) | Long-Term Firm Point-to-point Reservations (g) | Other Long-Term Firm Service (h) | Short-Term Firm Point-to-point Reservation (i) | Other Service (j)
| NAME OF SYSTEM: Georgia Power Company |  |  |  |  |  |  |  |  |
1 | January | (a) 28,747 | 27 | 8 | 110 | 599 | 1,986 |  | 935 | 25,117
2 | February | 25,910 | 13 | 7 | 97 | 418 | 1,986 |  | 359 | 23,050
3 | March | 27,678 | 20 | 8 | 105 | 452 | 1,986 |  | 259 | 24,876
4 | Total for Quarter 1 |  |  |  | 312 | 1,469 | 5,958 |  | 1,553 | 73,043
5 | April | 25,656 | 5 | 16 | 53 | 704 | 1,986 |  | 976 | 21,937
6 | May | 28,511 | 15 | 16 | 75 | 485 | 1,986 |  | 1,100 | 24,865
7 | June | 32,315 | 29 | 16 | 16 | 553 | 1,936 |  | 1,384 | 28,426
8 | Total for Quarter 2 |  |  |  | 144 | 1,742 | 5,908 |  | 3,460 | 75,228
9 | July | 33,858 | 20 | 16 | 98 | 537 | 1,936 |  | 1,387 | 29,900
10 | August | 34,988 | 14 | 16 | 105 | 495 | 1,936 |  | 1,804 | 30,648
11 | September | 32,180 | 6 | 16 | 88 | 773 | 1,936 |  | 1,594 | 27,789
12 | Total for Quarter 3 |  |  |  | 291 | 1,805 | 5,808 |  | 4,785 | 88,337
13 | October | 25,242 | 2 | 16 | 61 | 432 | 1,201 |  | 834 | 22,714
14 | November | 27,765 | 29 | 7 | 103 | 296 | 1,201 |  | 941 | 25,224
15 | December | 27,988 | 20 | 8 | 101 | 335 | 1,201 |  | 892 | 25,459
16 | Total for Quarter 4 |  |  |  | 265 | 1,063 | 3,603 |  | 2,667 | 73,397
17 | Total |  |  |  | 1,012 | 6,079 | 21,277 |  | 12,465 | 310,005

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: MonthlyPeakLoadExcludingIsoAndRto
The Southern Company electric operating companies (Alabama Power Company, Georgia Power Company, and Mississippi Power Company) collectively are the Transmission Provider under the Open Access Transmission Tariff and operate their transmission facilities as a single integrated system. Values shown correspond to the total transmission system peak loads on the Southern Company transmission system. Estimated load values are shown. The estimated loads are based on the customer's peak demand for previous month. Values are also based on telemetered load values using preliminary peak day and hour. The peak day and hour could change when actual loads are available.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No. | Month (a) | Monthly Peak MW - Total (b) | Day of Monthly Peak (c) | Hour of Monthly Peak (d) | Import into ISO/RTO (e) | Exports from ISO/RTO (f) | Through and Out Service (g) | Network Service Usage (h) | Point-to-Point Service Usage (i) | Total Usage (j)
| NAME OF SYSTEM: Enter System |  |  |  |  |  |  |  |  |
1 | January |  |  |  |  |  |  |  |  |
2 | February |  |  |  |  |  |  |  |  |
3 | March |  |  |  |  |  |  |  |  |
4 | Total for Quarter 1 |  |  |  |  |  |  |  |  |
5 | April |  |  |  |  |  |  |  |  |
6 | May |  |  |  |  |  |  |  |  |
7 | June |  |  |  |  |  |  |  |  |
8 | Total for Quarter 2 |  |  |  |  |  |  |  |  |
9 | July |  |  |  |  |  |  |  |  |
10 | August |  |  |  |  |  |  |  |  |
11 | September |  |  |  |  |  |  |  |  |
12 | Total for Quarter 3 |  |  |  |  |  |  |  |  |
13 | October |  |  |  |  |  |  |  |  |
14 | November |  |  |  |  |  |  |  |  |
15 | December |  |  |  |  |  |  |  |  |
16 | Total for Quarter 4 |  |  |  |  |  |  |  |  |
17 | Total Year to Date/Year |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 2024-04-01 | Year/Period of Report End of: 2023 / Q4

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No. | Item (a) | MegaWatt Hours (b) | Line No. | Item (a) | MegaWatt Hours (b)
1 | SOURCES OF ENERGY |  | 21 | DISPOSITION OF ENERGY |
2 | Generation (Excluding Station Use): |  | 22 | Sales to Ultimate Consumers (Including Interdepartmental Sales) | 84,130,035
3 | Steam | 13,856,799 | 23 | Requirements Sales for Resale (See instruction 4, page 311.) |
4 | Nuclear | 18,101,704 | 24 | Non-Requirements Sales for Resale (See instruction 4, page 311.) | 2,635,740
5 | Hydro-Conventional | 1,329,394 | 25 | Energy Furnished Without Charge |
6 | Hydro-Pumped Storage | 274,804 | 26 | Energy Used by the Company (Electric Dept Only, Excluding Station Use) | 95,935
7 | Other | 27,587,690 | 27 | Total Energy Losses | 3,574,849
8 | Less Energy for Pumping | 359,933 | 27.1 | Total Energy Stored |
9 | Net Generation (Enter Total of lines 3 through 8) | 60,790,458 | 28 | TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES | 90,436,559
10 | Purchases (other than for Energy Storage) | 29,637,093
10.1 | Purchases for Energy Storage |
11 | Power Exchanges: |
12 | Received | 17,776,641
13 | Delivered | 17,767,633
14 | Net Exchanges (Line 12 minus line 13) | 9,008
15 | Transmission For Other (Wheeling) |
16 | Received | 31,545,185
17 | Delivered | 30,986,494
18 | Net Transmission for Other (Line 16 minus line 17) | 558,691
19 | Transmission By Others Losses | 558,691
20 | TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19) | 90,436,559

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No. | MonthAxis Month (a) | EnergyActivity Total Monthly Energy (b) | NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c) | MonthlyPeakLoad Monthly Peak - Megawatts (d) | DayOfMonthlyPeak Monthly Peak - Day of Month (e) | HourOfMonthlyPeak Monthly Peak - Hour (f)
| NAME OF SYSTEM: Georgia Power Company |  |  |  |  |
29 | January | 7,390,512 | 109,756 | 14,035 | 24 | 6
30 | February | 6,368,343 | 82,792 | 12,374 | 13 | 6
31 | March | 7,070,871 | 274,768 | 13,075 | 20 | 7
32 | April | 6,691,534 | 249,461 | 12,070 | 5 | 15
33 | May | 7,252,304 | 207,506 | 13,914 | 16 | 15
34 | June | 7,850,395 | 248,316 | 15,107 | 29 | 14
35 | July | 9,314,296 | 277,452 | 16,314 | 20 | 14
36 | August | 9,356,960 | 277,506 | 16,720 | 14 | 15
37 | September | 7,717,554 | 178,524 | 15,195 | 6 | 15
38 | October | 6,849,242 | 221,969 | 12,448 | 4 | 15
39 | November | 6,909,921 | 278,072 | 13,663 | 29 | 6
40 | December | 7,664,627 | 229,618 | 14,227 | 20 | 7
41 | Total | 90,436,559 | 2,635,740 |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Steam Electric Generating Plant Statistics
1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf. 7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned. 9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No. | Item (a) | Plant Name: BOWEN | Plant Name: FORT BENNING | Plant Name: FORT GORDON | Plant Name: FORT STEWART | Plant Name: FORT VALLEY STATE UNIVERSITY | Plant Name: (a)(b) HATCH | Plant Name: KING'S BAY | Plant Name: MCDONOUGH NO. 3 | Plant Name: MCDONOUGH NO. 4-6 | Plant Name: MCINTOSH (CC) | Plant Name: MCINTOSH (CT) | Plant Name: MCLB | Plant Name: MCMANUS 3 & 4 | Plant Name: MOODY AFB | Plant Name: ROBINS AFB | Plant Name: (c) SCHERER | Plant Name: (d)(e) VOGTLE 1&2 | Plant Name: (f)(g) VOGTLE 3 | Plant Name: WARNER ROBINS | Plant Name: WILSON | Plant Name: YATES
1 | PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear) | STEAM | SOLAR PROJECT | SOLAR PROJECT | SOLAR PROJECT | SOLAR PROJECT | NUCLEAR | SOLAR PROJECT | COMBUSTION TURBINE | COMBINED CYCLE | COMBINED CYCLE | COMBUSTION TURBINE | SOLAR PROJECT | COMBUSTION TURBINE | SOLAR PROJECT | SOLAR PROJECT | STEAM | NUCLEAR | NUCLEAR | COMBUSTION TURBINE | COMBUSTION TURBINE | STEAM
2 | PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc) | CONVENTIONAL | OUTDOOR | OUTDOOR | OUTDOOR | OUTDOOR | 0 | OUTDOOR | (PEAK LOAD) INDOOR | OUTDOOR | OUTDOOR |  | OUTDOOR | (PEAK LOAD) INDOOR | OUTDOOR | OUTDOOR | CONVENTIONAL | 0 | 0 | 0 | 0 | CONVENTIONAL
3 | YearPlantOriginallyConstructed Year Originally Constructed | 1971 | 2015 | 2016 | 2016 | 2022 | 1974 | 2016 | 1971 | 2011 | 2005 | 1993 | 2018 | 1971 | 2020 | 2021 | 1981 | 1987 | 2023 | 1995 | 1972 | 1950
4 | YearLastUnitOfPlantInstalled Year Last Unit was Installed | 1975 | 2015 | 2016 | 2016 | 2022 | 1978 | 2016 | 1971 | 2012 | 2005 | 1994 | 2018 | 1972 | 2020 | 2021 | 1988 | 1987 | 2023 | 1995 | 1973 | 1974
5 | InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW) | 3,499.00 | 30.01 | 30.00 | 30.00 | 10.80 | 926.00 | 30.16 | 84.00 | 2,764.50 | 1,376.50 | 811.00 | 31.16 | 560.00 | 49.50 | 128.00 | 818.00 | 1,110.00 | 1,211.00 | 184.00 | 318.00 | 808.00
6 | NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes) | 3,089 | 30 | 31 | 31 | 11 | 906 | 30 | 28 | 2,787 | 1,392 | 407 | 30 | 217 | 50 | 129 | 773 | 1,097 | 1,146 | 161 | 109 | 704
7 | PlantHoursConnectedToLoad Plant Hours Connected to Load | 8,759 | 4,063 | 3,995 | 3,967 | 3,734 | 8,759 | 4,111 | 7 | 8,759 | 8,759 | 330 | 4,095 | 86 | 4,224 | 4,179 | 8,206 | 8,759 | 3,697 | 28 | 88 | 7,742
8 | NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts) | 0 | 30 | 30 | 30 | 11 | 0 | 30 | 0 | 0 | 0 | 0 | 31 | 0 | 50 | 128 | 0 | 0 |  | 0 | 0 | 0
9 | NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water | 3,120 | 0 | 0 | 0 | 0 | 881 | 0 | 64 | 2,175 | 1,034 | 658 | 0 | 414 | 0 | 0 | 789 | 1,078 | 1,196 | 160 | 295 | 699
10 | NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |  | 0 | 0 | 0
11 | PlantAverageNumberOfEmployees Average Number of Employees | 425 | 0 | 0 | 0 | 0 | 959 | 0 | 0 | 73 | 37 | 0 | 0 | 0 | 0 | 0 | 419 | 925 |  | 0 | 0 | 70
12 | NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh | 10,228,093,000 | 51,472,000 | 54,727,000 | 51,230,000 | 20,595,000 | 7,184,452,224 | 55,658,000 | 140,000 | 17,824,685,000 | 9,107,240,000 | 18,174,000 | 53,906,000 | 130,000 | 92,957,000 | 225,198,000 | 6,461,453,000 | 8,536,906,697 | 1,869,976,364 | 331,000 | 753,000 | 2,239,181,000
13 | CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights | 27,893,122 |  |  |  |  | 599,935 |  |  | 35,623,203 | 346,942 |  |  | 995,638 |  |  | 6,329,280 | 487,959 |  |  | 37,881 | 1,030,932
14 | CostOfStructuresAndImprovementsSteamProduction Structures and Improvements | 545,424,193 |  |  |  |  | 207,242,597 |  | 788,855 | 78,786,379 | 42,244,656 | 44,823,275 | 211,611 | 3,779,145 |  |  | 181,835,300 | 1,171,535,956 | 3,544,595,378 | 3,332,753 | 1,441,426 | 56,637,531
15 | CostOfEquipmentSteamProduction Equipment Costs | 4,541,345,496 | 67,299,135 | 67,101,460 | 67,091,072 | 22,844,496 | 1,183,524,735 | 67,635,369 | 21,860,272 | 1,625,762,060 | 600,933,370 | 175,714,894 | 69,142,382 | 63,537,642 | 75,182,097 | 189,639,422 | 1,357,273,616 | 2,415,141,618 |  | 36,953,050 | 43,351,461 | 327,958,692
16 | AssetRetirementCostsSteamProduction Asset Retirement Costs | 643,936,000 |  |  |  |  | 184,323,502 |  |  | 117,695 | 594,515 | 318,346 |  | 216,864 |  |  | 95,146,342 | 112,859,167 | 89,480,043 | 23,093 | 336,430 | 7,905,333
17 | CostOfPlant Total cost (total 13 thru 20) | 5,758,598,811 | 67,299,135 | 67,101,460 | 67,091,072 | 22,844,496 | 1,575,690,769 | 67,635,369 | 22,649,127 | 1,740,289,337 | 644,119,483 | 220,219,823 | 69,353,993 | 68,529,289 | 75,182,097 | 189,639,422 | 1,640,584,538 | 3,700,024,700 | 3,634,075,421 | 40,308,896 | 45,167,198 | 393,532,488
18 | CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including | 1,645.7842 | 2,242.5570 | 2,236.7153 | 2,236.3691 | 2,115.2311 | 1,701.6099 | 2,242.5520 | 269.6325 | 629.5132 | 467.9401 | 271.5411 | 2,225.7379 | 122.3737 | 1,518.8302 | 1,481.5580 | 2,005.6046 | 3,333.3556 | 3,000.8880 | 219.0701 | 142.0352 | 487.0452
19 | OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr | 11,275,664 | 15,071 | 14,590 | 14,356 | 5,168 | 45,597,619 | 14,433 | 22,929 | 4,009,056 | 1,787,010 | 897,882 | 14,912 | 309,999 | 24,301 | 61,252 | 3,332,252 | 45,441,066 | 11,087,436 | 195,373 | 199,973 | 1,183,481
20 | FuelSteamPowerGeneration Fuel | 557,458,240 |  |  |  |  | 54,815,423 |  | 114,840 | 531,704,827 | 248,473,628 | 1,839,989 |  | 734,646 |  |  | 96,803,329 | 59,942,634 | 29,542,293 | 296,143 | 1,142,346 | 93,422,743
21 | CoolantsAndWater Coolants and Water (Nuclear Plants Only) |  |  |  |  |  | 4,857,580 |  |  |  |  |  |  |  |  |  |  | 4,386,557 | 1,971,792 |  |  |
22 | SteamExpensesSteamPowerGeneration Steam Expenses | 24,665,510 | 40,921 | 44,246 | 27,632 | 46,586 | 7,818,443 | 53,210 |  | 4,114,110 | 2,628,431 | 944,470 | 93,714 | 129,798 | 67,476 | 133,515 | 1,634,460 | 6,156,714 | 1,333,292 | 249,734 | 316,451 | 34,185
23 | SteamFromOtherSources Steam From Other Sources |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
24 | SteamTransferredCredit Steam Transferred (Cr) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
25 | ElectricExpensesSteamPowerGeneration Electric Expenses | 11,968,773 |  |  |  |  | 100,119 |  |  |  |  |  |  |  |  |  | 1,174,535 |  | 2,325 |  |  | 4,328,290
26 | MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses | 18,929,906 | 58,983 | 47,612 | 70,822 | 17,308 | 59,446,587 | 54,565 | 106,933 | 7,047,453 | 1,739,029 | 1,649,545 | 54,569 | 1,258,551 | 82,572 | 222,814 | 8,923,983 | 57,966,955 | 13,941,242 | 240,881 | 111,402 | 4,304,507
27 | RentsSteamPowerGeneration Rents |  |  |  |  |  | 230,568 |  |  |  |  |  |  |  |  |  |  | 151,023 | 103,415 |  |  |
28 | Allowances Allowances | 7,377 |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 6,558 |  |  |  |  | 1,634
29 | MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering | 6,300,506 |  |  |  |  | 12,510,406 |  | 256 | 1,250,337 | 816,471 | 96,138 |  | 90,414 |  |  | 1,518,039 | 8,042,935 | 6,233,219 | 6,958 | 35,855 | 795,784
30 | MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures | 6,295,603 | 72 | 72 | 104,306 | 21,200 | 1,558,641 | 72 | 3,093 | 5,323,103 | 1,984,784 | 1,013,458 | 74 | 355,581 | 118 | 577,850 | 2,590,545 | 1,458,356 | 606,332 | 104,259 | 495,526 | 1,866,797
31 | MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant | 44,747,394 |  |  |  |  | 3,959,512 |  |  |  |  |  |  |  |  |  | 9,595,009 | 4,481,464 | 140,522 |  |  | 3,014,418
32 | MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant | 7,783,572 | 216,090 | 204,499 | 403,299 | 199,170 | 4,978,146 | 287,314 | 1,488 | 29,898,339 | 7,911,992 | 3,130,058 | 407,454 | 1,407,520 | 273,861 | 600,398 | 1,127,377 | 4,029,464 | 1,961,073 | 309,318 | 1,398,793 | 1,056,393
33 | MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant | 3,249,900 | 31,507 | 92,917 | 33,761 | 4,653 | 9,219,255 | 40,908 |  | 551,537 | 822,823 | 457,139 | 59,585 | 115,853 | 42,414 | 63,650 | 1,036,636 | 13,270,922 | 800,617 | 64,795 | 92,624 | 572,342
34 | PowerProductionExpensesSteamPower Total Production Expenses | 692,682,445 | 362,644 | 403,936 | 654,176 | 294,085 | 205,092,299 | 450,502 | 249,539 | 583,898,762 | 266,164,168 | 10,028,679 | 630,308 | 4,402,362 | 490,742 | 1,659,479 | 127,742,723 | 205,328,090 | 67,723,558 | 1,467,461 | 3,792,970 | 110,580,574
35 | ExpensesPerNetKilowattHour Expenses per Net kWh | 0.0677 | 0.0070 | 0.0074 | 0.0128 | 0.0143 | 0.0285 | 0.0081 | 1.7824 | 0.0328 | 0.0292 | 0.5518 | 0.0117 | 33.8643 | 0.0053 | 0.0074 | 0.0198 | 0.0241 | 0.0362 | 4.4334 | 5.0371 | 0.0494

35 | FuelKindAxis Plant Name | BOWEN | BOWEN | HATCH | MCDONOUGH NO. 3 | MCDONOUGH NO. 3 | MCDONOUGH NO. 4-6 | MCDONOUGH NO. 4-6 | MCINTOSH (CC) | MCINTOSH (CT) | MCINTOSH (CT) | MCMANUS 3 & 4 | SCHERER | SCHERER | VOGTLE 1&2 | VOGTLE 3 | WARNER ROBINS | WARNER ROBINS | WILSON | YATES
36 | FuelKind Fuel Kind | Coal | Oil | Nuclear | Gas | OIl | Gas | Oil | Gas | Gas | Oil | Oil | Coal | Oil | Nuclear | Nuclear | Gas | Oil | Oil | Gas
37 | FuelUnit Fuel Unit | T | bbl | g | Mcf | bbl | Mcf | bbl | Mcf | Mcf | bbl | bbl | T | bbl | g | g | Mcf | bbl | bbl | Mcf
38 | QuantityOfFuelBurned Quantity (Units) of Fuel Burned | 4,259,094 | 30,827 | 1,198,545 | 0 | 1,017 | 120,606,415 |  | 62,035,245 | 311,791 | 6,675 | 5,505 | 1,583,316 | 8,062 | 1,400,998 | 463,262 | 7,862 | 766 | 10,709 | 23,472,271.000
39 | FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) | 11,767 | 6 | 61,692,331 | 0 | 6 | 1,031 |  | 1,028 | 1,030 | 6 | 6 | 7,707 | 6 | 64,159,833 | 33,457,254 | 1,032 | 6 | 6 | 1,026.000
40 | AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year | 129.895 | 129.030 | 45.750 |  | 133.885 | 3.841 |  | 3.447 | 2.946 | 144.370 | 105.182 | 58.577 | 145.058 | 42.667 | 63.770 | 18.551 | 127.767 | 105.497 | 3.420
41 | AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned | 129.895 | 129.030 | 45.750 |  | 133.885 | 3.841 |  | 3.447 | 2.946 | 144.370 | 105.182 | 58.577 | 145.058 | 42.667 | 63.770 | 18.551 | 127.767 | 105.497 | 3.420
42 | AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU | 5.519 | 22.182 | 0.742 |  | 23.017 | 3.727 |  | 3.353 | 2.861 | 24.819 | 18.082 | 3.800 | 24.935 | 0.665 | 1.906 | 17.977 | 21.963 | 18.136 | 3.332
43 | AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen | 0.054 |  | 0.008 |  |  | 0.026 |  | 0.023 | 0.051 |  | 4.907 | 0.067 |  | 0.007 | 0.012 | 0.441 |  | 1.052 | 0.036
44 | AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation | 9,799.875 |  | 10,291.810 |  |  | 6,972.711 |  | 7,003.303 | 17,666.226 |  | 271,372.881 | 17,563.223 |  | 10,529.320 | 6,511.440 | 24,510.574 |  | 58,001.862 | 10,760.186

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: PlantName
Plant Vogtle and Plant Hatch, are jointly owned with Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and the City of Dalton.
(b) Concept: PlantName
After nuclear fuel is placed in the reactor, the cost of fuel is amortized on the basis of quantity of heat produced, therefore matching the cost of the fuel with the power produced. b) Uranium: lbs Conversion: Kilograms of uranium (kgU) Enrichment: Separative work units (SWU) Fabrication: Assemblies c) Type of fuel Used: Uranium Enrichment: 4-5% Fuel Array: 10 x 10 Fuel Assemblies: 560 Assemblies per Unit Active Length of Fuel Assembly: Approximately 12.5 feet Fuel Rods per Assembly: 96 Reactors: Two Boiling Water Reactors (BWRs) manufactured by General Electric Company
(c) Concept: PlantName
Plant Scherer is jointly owned with Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, the City of Dalton, Florida Power and Light Company, and Jacksonville Electric Authority.
(d) Concept: PlantName
Plant Vogtle and Plant Hatch, are jointly owned with Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and the City of Dalton.
(e) Concept: PlantName
After nuclear fuel is placed in the reactor, the cost of fuel is amortized on the basis of quantity of heat produced, therefore matching the cost of the fuel with the power produced. b) Uranium: lbs Conversion: Kilograms of uranium (kgU) Enrichment: Separative work units (SWU) Fabrication: Assemblies c) Type of fuel Used: Uranium Enrichment: 4-5% Fuel Array: 17 x 17 Fuel Assemblies: 193 Assemblies per Unit Active Length of Fuel Assembly: Approximately 12 feet Fuel Rods per Assembly: 264 Reactors: Two Pressurized Water Reactors (PWRs) manufactured by Westinghouse Electric Company
(f) Concept: PlantName
Plant Vogtle and Plant Hatch, are jointly owned with Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and the City of Dalton.
(g) Concept: PlantName
After nuclear fuel is placed in the reactor, the cost of fuel is amortized on the basis of quantity of heat produced, therefore matching the cost of the fuel with the power produced. b) Uranium: lbs Conversion: Kilograms of uranium (kgU) Enrichment: Separative work units (SWU) Fabrication: Assemblies c) Type of fuel Used: Uranium Enrichment: 4-5% Fuel Array: 17 x 17 Fuel Assemblies: 157 Assemblies per unit Active Fuel Length of Assembly: Approximately 14 feet Fuel Rods per Assembly: 264 Reactors: One Pressurized Water Reactor (PWR) manufactured by Westinghouse Electric Company

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Hydroelectric Generating Plant Statistics
Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number. If net peak demand for 60 minutes is not available, give that which is available specifying period. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No. | Item (a) | FERC Licensed Project No. 0 Plant Name: 0 | FERC Licensed Project No. 1951 Plant Name: SINCLAIR DAM | FERC Licensed Project No. 2177 Plant Name: GOAT ROCK | FERC Licensed Project No. 2177 Plant Name: NORTH HIGHLANDS | FERC Licensed Project No. 2177 Plant Name: OLIVER DAM | FERC Licensed Project No. 2237 Plant Name: MORGAN FALLS | FERC Licensed Project No. 2336 Plant Name: LLOYD SHOALS | FERC Licensed Project No. 2354 Plant Name: MATHIS-TERRORA | FERC Licensed Project No. 2354 Plant Name: TALLULAH FALLS | FERC Licensed Project No. 2354 Plant Name: TUGALO | FERC Licensed Project No. 2354 Plant Name: YONAH | FERC Licensed Project No. 2413 Plant Name: WALLACE DAM | FERC Licensed Project No. 485 Plant Name: BARTLETTS FERRY
1 | PlantKind Kind of Plant (Run-of-River or Storage) |  | Storage | Run-of-River | Run-of-River | Run-of-River | Run-of-River | Storage | Storage | Run-of-River | Run-of-River | Run-of-River | Storage | Storage
2 | PlantConstructionType Plant Construction type (Conventional or Outdoor) |  | Conventional | Conventional | Conventional | Conventional | Conventional | Conventional | Conventional | Conventional | Conventional | Conventional | Semi-Outdoor | Conventional
3 | YearPlantOriginallyConstructed Year Originally Constructed |  | 1953 | 1912 | 1963 | 1959 | 1903 | 1911 | 1925 | 1913 | 1923 | 1925 | 1979 | 1926
4 | YearLastUnitOfPlantInstalled Year Last Unit was Installed |  | 1953 | 2005 | 1963 | 1959 | 1923 | 1916 | 1925 | 1920 | 1924 | 1925 | 1980 | 1985
5 | InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |  | 45 | 39 | 29.6 | 60 | 16.8 | 14.4 | 16 | 67 | 45 | 22.5 | 112.5 | 173
6 | NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes) |  | 44 | 33 | 38 | 58 | 12 | 18 | 18 | 6,968 | 36 | 24 | 320 | 170
7 | PlantHoursConnectedToLoad Plant Hours Connect to Load |  | 8,436 | 8,116 | 6,956 | 5,573 | 8,390 | 8,742 | 4,307 | 4,144 | 4,022 | 5,535 | 1,845 | 5,789
8 | NetPlantCapabilityAbstract Net Plant Capability (in megawatts) |  |  |  |  |  |  |  |  |  |  |  |  |
9 | NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions |  | 44 | 40 | 35 | 59 | 11 | 23 | 17 | 73 | 52 | 29 | 115 | 192
10 | NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions |  | 44 | 39 | 34 | 58 | 11 | 23 | 17 | 73 | 52 | 29 | 115 | 190
11 | PlantAverageNumberOfEmployees Average Number of Employees |  |  |  |  |  |  |  |  |  |  |  |  |
12 | NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |  | 120,162,000 | 99,371,000 | 98,028,000 | 134,373,000 | 29,204,000 | 70,294,000 | 34,739,000 | 100,416,000 | 43,577,000 | 35,023,000 | 197,760,000 | 396,974,000
13 | CostOfPlantAbstract Cost of Plant |  |  |  |  |  |  |  |  |  |  |  |  |
14 | CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights |  | 2,130,875 | 586,559 | 204,939 | 861,147 | 2,940 | 881,780 | 101,777 | 409,265 | 196,578 | 41,465 | 8,067,519 | 53,507
15 | CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements |  | 3,320,091 | 2,365,122 | 2,484,450 | 2,690,521 | 1,201,849 | 2,744,762 | 2,398,579 | 3,952,028 | 3,895,591 | 1,227,361 | 12,301,875 | 20,779,874
16 | CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways |  | 10,282,395 | 10,111,833 | 6,881,077 | 6,798,099 | 8,417,063 | 12,847,000 | 17,063,059 | 14,110,114 | 11,207,268 | 6,465,796 | 27,978,770 | 22,440,330
17 | EquipmentCostsHydroelectricProduction Equipment Costs |  | 8,859,460 | 21,466,376 | 5,314,860 | 9,976,597 | 12,239,281 | 13,009,594 | 42,777,952 | 20,677,736 | 57,612,706 | 3,016,659 | 30,069,550 | 44,974,626
18 | CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges |  | 41,522 | 52,308 | 37,614 | 349,257 | 36,694 | 48,818 | 134,365 | 1,534,836 | 561,750 | 43,277 | 644,375 | 137,626
19 | AssetRetirementCostsHydroelectricProduction Asset Retirement Costs |  | 136,784 | 65,247 | 280,817 | 516,383 | 283,312 | 154,044 | 448,205 | 1,194,227 | 1,184,049 | 816,920 | 29,510 |
20 | CostOfPlant Total cost (total 13 thru 20) |  | 24,771,127 | 34,647,445 | 15,203,757 | 21,192,004 | 22,181,139 | 29,685,998 | 62,923,937 | 41,878,206 | 74,657,942 | 11,611,478 | 79,091,599 | 88,385,963
21 | CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5) |  | 550.5 | 888.4 | 513.6 | 353.2 | 1,320.3 | 2,061.5 | 3,932.7 | 625.0 | 1,659.1 | 516.1 | 703.0 | 510.9
22 | ProductionExpensesAbstract Production Expenses |  |  |  |  |  |  |  |  |  |  |  |  |
23 | OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |  | 343,928 | 110,023 | 406,474 | 630,542 | 312,039 | 80,090 | 53,927 | 183,092 | 115,108 | 57,138 | 439,184 | 881,023
24 | WaterForPower Water for Power |  |  | 460,004 | 266,046 | 484,367 | 103,339 |  |  |  |  |  |  | 593,771
25 | HydraulicExpenses Hydraulic Expenses |  | 138 | 124 | 91 | 184 | 52 | 55 | 64 | 221 | 138 | 69 | 422 | 531
26 | ElectricExpensesHydraulicPowerGeneration Electric Expenses |  | 63,869 | 27,864 | 11,831 | 7,201 | 921,975 | 96,630 | 3,294 | 12,574 | 2,058 | 1,029 | 506,461 | 1,391,963
27 | MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses |  | 48,031 | 25,562 | 32,567 | 68,474 | 99,169 | 37,203 | 13,991 | 45,445 | 33,670 | 14,201 | 107,783 | 119,031
28 | RentsHydraulicPowerGeneration Rents |  |  |  |  |  |  |  |  |  |  |  | 21,661 |
29 | MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering |  | 1,000 | 900 | 658 | 1,334 | 373 | 400 | 462 | 1,600 | 1,000 | 500 | 3,059 | 3,845
30 | MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures |  | 533,254 | 82,429 | 18,468 | 27,181 | 130,103 | 111,635 | 16,457 | 41,522 | 20,072 | 34,221 | 169,685 | 102,618
31 | MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways |  | 79,129 | 170,933 | 26,287 | 52,154 | 243,847 | 147,707 | 2,478 | 26,516 | 28,721 | 4,700 | 208,615 | 177,073
32 | MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant |  | 86,722 | 69,528 | 79,063 | 219,885 | 273,619 | 369,461 | 161,210 | 95,183 | 77,652 | 130,440 | 729,503 | 211,923
33 | MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant |  | 21,451 | 3,823 | 14,611 | 19,225 | 75,173 | 2,143 | 1,498 |  |  |  | 16,757 | 52,924
34 | PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33) |  | 111,014 | 951,190 | 856,096 | 1,510,547 | 2,159,689 | 845,324 | 253,381 | 406,153 | 278,419 | 242,298 | 2,203,130 | 3,534,702
35 | ExpensesPerNetKilowattHour Expenses per net kWh | 0.0000 | 0.0009 | 0.0096 | 0.0087 | 0.0112 | 0.0740 | 0.0120 | 0.0073 | 0.0040 | 0.0064 | 0.0069 | 0.0111 | 0.0089

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give that which is available, specifying period. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No. | Item (a) | FERC Licensed Project No. 0 Plant Name: ROCKY MOUNTAIN | FERC Licensed Project No. 2413 Plant Name: WALLACE DAM
1 | PlantConstructionType Type of Plant Construction (Conventional or Outdoor) | (a) 0 | SEMI-OUTDOOR
2 | YearPlantOriginallyConstructed Year Originally Constructed | 1995 | 1979
3 | YearLastUnitOfPlantInstalled Year Last Unit was Installed | 1995 | 1980
4 | InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) | 278 | 209
5 | NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes) | 260 | 210
6 | PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating | 3,575 | 1,404
7 | NetContinuousPlantCapability Net Plant Capability (in megawatts) | 190 | 213
8 | PlantAverageNumberOfEmployees Average Number of Employees |  |
9 | NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh | 177,910,509 | 96,893,000
10 | EnergyUsedForPumping Energy Used for Pumping | 230,886,076 | 129,047,000
11 | NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh | 52,975,567 | 32,154,000
12 | CostOfPlantAbstract Cost of Plant |  |
13 | CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights | 1,959,330 | 16,379,508
14 | CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements | 40,451,499 | 24,976,534
15 | CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways | 72,942,747 | 56,805,381
16 | CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators | 42,734,015 | 43,718,006
17 | CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment | 12,245,697 | 8,646,986
18 | CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment | 4,166,885 | 8,685,306
19 | CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges | 3,116,744 | 1,308,277
20 | AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs |  | 59,914
21 | CostOfPlant Total cost (total 13 thru 20) | 177,616,917 | 160,579,912
22 | CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4) | 638.9 | 768.3
23 | ProductionExpensesAbstract Production Expenses |  |
24 | OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering | 3,464,104 | 586,195
25 | WaterForPower Water for Power |  |
26 | PumpedStorageExpenses Pumped Storage Expenses |  | 563
27 | ElectricExpensesPumpedStoragePlant Electric Expenses |  | 675,993
28 | MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses | 564,399 | 143,862
29 | RentsPumpedStoragePlant Rents |  | 28,912
30 | MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering |  | 4,083
31 | MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures |  | 226,485
32 | MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways |  | 278,446
33 | MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant |  | 973,696
34 | MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant |  | 22,367
35 | PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34) | 4,028,503 | 2,940,602
36 | PumpingExpenses Pumping Expenses |  |
37 | PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36) | 4,028,503 | 2,940,602
38 | ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9) | 0.0226 | 0.0303
39 | ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10)) | 0 | 0

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: PlantConstructionType
Rocky Mountain is jointly owned with Oglethorpe Power Corporation.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
|  |  |  |  |  |  |  |  | Production Expenses |  |  |
Line No. | PlantName Name of Plant (a) | YearPlantOriginallyConstructed Year Orig. Const. (b) | InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c) | NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d) | NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e) | CostOfPlant Cost of Plant (f) | PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g) | OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h) | FuelProductionExpenses Fuel Production Expenses (i) | MaintenanceProductionExpenses Maintenance Production Expenses (j) | FuelKind Kind of Fuel (k) | FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l) | GenerationType Generation Type (m)
1 | Hydro: |  |  |  |  |  |  |  |  |  |  |  |
2 | Burton (A) | 1927 | 8.10 | 8.00 | 17,005,000 | 15,232,551 | 2,105,791 | 26,047 |  | 160,189 |  |  | Hydro
3 | Nacoochee (A) | 1926 | 4.80 | 6.00 | 12,009,000 | 8,166,312 | 1,637,178 | 15,453 |  | 123,732 |  |  | Hydro
4 | Flint River (B) | 1921 | 5.40 | 7.00 | 37,352,000 | 24,909,699 | 3,216,354 | 833,660 |  | 348,868 |  |  | Hydro
5 | Estatoah - Retired (C) |  | 0.20 | 0.00 | 0 | 75 | 305,690 |  |  |  |  |  | Hydro
6 | Langdale - Retired (D) | 1907 | 1.00 | 0.00 | 0 | 2,707 | 1,816,188 | 4,054 |  |  |  |  | Hydro
7 | Riverview - Retired (E) | 1918 | 0.50 | 0.00 | 0 | 757 | 1,254,446 | 2,672 |  | 8,545 |  |  | Hydro
8 | Solar: |  |  |  |  |  |  |  |  |  |  |  |
9 | (a) Various |  | 18.50 | 0.00 | 30,033,480 | 47,646,935 | 2,480,761 | 128,911 |  | 414,810 |  |  | Solar
10 | (A) Licensed Project Number 2354. |  |  |  |  |  |  |  |  |  |  |  |
11 | (B) Licensed Project Number 1218. |  |  |  |  |  |  |  |  |  |  |  |
12 | (C) Approximately 1928. Record of Owners inadeq. |  |  |  |  |  |  |  |  |  |  |  |
13 | (D) Licensed Project Number 2341. |  |  |  |  |  |  |  |  |  |  |  |
14 | (E) Licensed Project Number 2350. |  |  |  |  |  |  |  |  |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: PlantName
Various Solar consists of Dalton, University of Georgia, Falcons Solar Projects, Tri-County Solar Projects, Guyton, Comer, Waynesboro, and LaGrange.

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 Kw or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No. | Name of the Energy Storage Project (a) | Functional Classification (b) | Location of the Project (c) | MWHs (d) | MWHs delivered to the grid to support Production (e) | MWHs delivered to the grid to support Transmission (f) | MWHs delivered to the grid to support Distribution (g) | MWHs Lost During Conversion, Storage and Discharge of Energy Production (h) | MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i) | MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j) | MWHs Sold (k) | Revenues from Energy Storage Operations (l) | Power Purchased for Storage Operations (555.1) (Dollars) (m) | Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n) | Other Costs Associated with Self-Generated Power (Dollars) (o) | Account for Project Costs (p) | Production (Dollars) (q) | Transmission (Dollars) (r) | Distribution (Dollars) (s)
1 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
2 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
3 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
4 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
5 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
6 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
7 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
8 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
9 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
11 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
12 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
13 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
14 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
15 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
16 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
17 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
18 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
19 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
20 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
21 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
22 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
23 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
24 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
25 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
26 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
27 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
28 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
29 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
30 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
31 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
32 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
33 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
34 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
35 | TOTAL |  |  | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |  | 0 | 0 | 0

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

ENERGY STORAGE OPERATIONS (Small Plants)
Small Plants are plants less than 10,000 Kw. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. If any other expenses, report in column (i) and footnote the nature of the item(s).
|  |  |  |  | BALANCE AT BEGINNING OF YEAR
Line No. | Name of the Energy Storage Project (a) | Functional Classification (b) | Location of the Project (c) | Project Cost (d) | Operations (Excluding Fuel used in Storage Operations) (e) | Maintenance (f) | Cost of fuel used in storage operations (g) | Account No. 555.1, Power Purchased for Storage Operations (h) | Other Expenses (i)
1 |  |  |  |  |  |  |  |  |
2 |  |  |  |  |  |  |  |  |
3 |  |  |  |  |  |  |  |  |
4 |  |  |  |  |  |  |  |  |
5 |  |  |  |  |  |  |  |  |
6 |  |  |  |  |  |  |  |  |
7 |  |  |  |  |  |  |  |  |
8 |  |  |  |  |  |  |  |  |
9 |  |  |  |  |  |  |  |  |
10 |  |  |  |  |  |  |  |  |
11 |  |  |  |  |  |  |  |  |
12 |  |  |  |  |  |  |  |  |
13 |  |  |  |  |  |  |  |  |
14 |  |  |  |  |  |  |  |  |
15 |  |  |  |  |  |  |  |  |
16 |  |  |  |  |  |  |  |  |
17 |  |  |  |  |  |  |  |  |
18 |  |  |  |  |  |  |  |  |
19 |  |  |  |  |  |  |  |  |
20 |  |  |  |  |  |  |  |  |
21 |  |  |  |  |  |  |  |  |
22 |  |  |  |  |  |  |  |  |
23 |  |  |  |  |  |  |  |  |
24 |  |  |  |  |  |  |  |  |
25 |  |  |  |  |  |  |  |  |
26 |  |  |  |  |  |  |  |  |
27 |  |  |  |  |  |  |  |  |
28 |  |  |  |  |  |  |  |  |
29 |  |  |  |  |  |  |  |  |
30 |  |  |  |  |  |  |  |  |
31 |  |  |  |  |  |  |  |  |
32 |  |  |  |  |  |  |  |  |
33 |  |  |  |  |  |  |  |  |
34 |  |  |  |  |  |  |  |  |
35 |  |  |  |  |  |  |  |  |
36 | TOTAL |  |  | 0 | 0 | 0 | 0 | 0 | 0

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
| DESIGNATION | VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) |  | LENGTH (Pole miles) - (In the case of underground lines report circuit miles) |  |  | COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) | EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No. | TransmissionLineStartPoint From | TransmissionLineEndPoint To | OperatingVoltageOfTransmissionLine Operating | DesignedVoltageOfTransmissionLine Designated | SupportingStructureOfTransmissionLineType Type of Supporting Structure | LengthForStandAloneTransmissionLines On Structure of Line Designated | LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line | NumberOfTransmissionCircuits Number of Circuits | SizeOfConductorAndMaterial Size of Conductor and Material | CostOfLandAndLandRightsTransmissionLines Land | ConstructionAndOtherCostsTransmissionLines Construction Costs | OverallCostOfTransmissionLine Total Costs | OperatingExpensesOfTransmissionLine Operation Expenses | MaintenanceExpensesOfTransmissionLine Maintenance Expenses | RentExpensesOfTransmissionLine Rents | OverallExpensesOfTransmissionLine Total Expenses
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) | (k) | (l) | (m) | (n) | (o) | (p)
1 | 500 KV STEEL STRUCTURES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
2 | BOWEN | NORCROSS 500 KV LN | 500.00 | 500.00 | Steel Towers | 57.30 | 11.73 | 1 | 1113 ACSR | 2,183,682 | 34,119,421 | 36,303,103 |  |  |  |
3 | BOWEN | TVA 500 KV LN | 500.00 | 500.00 | Steel Towers | 43.04 |  | 1 | 1113 ACSR | 944,333 | 12,857,322 | 13,801,655 |  |  |  |
4 | BOWEN | UNION CITY #1 500 KV LN | 500.00 | 500.00 | Steel Towers | 48.82 |  | 1 | 1113 ACSR | 3,112,730 | 12,662,761 | 15,775,491 |  |  |  |
5 | BOWEN | UNION CITY #2 500 KV LN | 500.00 | 500.00 | Steel Towers | 57.63 |  | 1 | 1113 ACSR | 18,694 | 13,231,295 | 13,249,989 |  |  |  |
6 | FARLEY | NORTH TIFTON 500 KV LN | 500.00 | 500.00 | Steel Towers | 96.33 |  | 1 | 1113 ACSR | 1,109,253 | 20,162,850 | 21,272,103 |  |  |  |
7 | FORTSO | N TIFTON 500 KV LN | 500.00 | 500.00 | Steel Towers | 116.57 |  | 1 | 1113 ACSR | 5,303,002 | 41,516,040 | 46,819,042 |  |  |  |
8 | HATCH | OFFERMAN-FLA ST LN 500 KV L | 500.00 | 500.00 | Steel Towers | 88.67 |  | 1 | 1113 ACSR | 2,589,530 | 31,324,408 | 33,913,938 |  |  |  |
9 | HATCH | THALMANN-DUVAL 500 KV LN | 500.00 | 500.00 | Steel Towers | 105.91 |  | 1 | 1113 ACSR | 3,473,477 | 35,884,909 | 39,358,386 |  |  |  |
10 | NORCROSS | OCONEE LN 500 KV LN | 500.00 | 500.00 | Steel Towers | 79.10 |  | 1 | 1113 ACSR | 5,346,403 | 20,141,128 | 25,487,531 |  |  |  |
11 | SCHERER | WALLACE DAM 500 KV LN | 500.00 | 500.00 | Steel Towers | 53.43 |  | 1 | 1113 ACSR | 2,467,698 | 20,708,516 | 23,176,214 |  |  |  |
12 | PLANT VOGTLE | KLONDIKE 500KV LN |  |  |  |  |  |  |  |  | 8,155 | 8,155 |  |  |  |
13 | PLT SCHERER | O'HARA 500KV LN |  |  |  |  |  |  |  | 221,779 |  | 221,779 |  |  |  |
14 | VOGTLE | MCINTOSH-THALMANN 500 KV LN | 500.00 | 500.00 | Steel Towers | 221.21 |  | 1 | 1113 ACSR | 6,325,877 | 70,643,803 | 76,969,680 |  |  |  |
15 | VOGTLE | WADLEY 500 KV LN | 500.00 | 500.00 | Steel Towers | 43.55 |  | 1 | 1113 ACSR | 1,719,545 | 18,458,017 | 20,177,562 |  |  |  |
16 | WANSLEY | OHARA 500 KV LN | 500.00 | 500.00 | Steel Towers | 50.78 |  | 1 | 1113 ACSR | 2,707,634 | 14,941,879 | 17,649,513 |  |  |  |
17 | WADLEY | WALLACE DAM 500 KV LN | 500.00 | 500.00 | Steel Towers | 57.02 |  | 1 | 1113 ACSR | 2,475,480 | 21,261,710 | 23,737,190 |  |  |  |
18 | MCGRAU FORD | MOSTELLER SPRINGS | 500.00 | 500.00 | Steel Towers | 34.50 |  | 1 | 1113 ACSR | 19,321,411 | 76,855,221 | 96,176,632 |  |  |  |
19 | VOGTLE BUS #1 | VOGTLE 3&4 BUS #3 | 500.00 | 500.00 | Steel Towers | 0.19 |  | 1 | 1113 ACSR |  |  |  |  |  |  |
20 | VOGTLE BUS #2 | VOGTLE 3&4 BUS #4 | 500.00 | 500.00 | Steel Towers | 0.19 |  | 1 | 1113 ACSR |  |  |  |  |  |  |
21 | THOMSON | VOGTLE 500 KV LINE | 500.00 | 500.00 | Steel Towers | 55.21 |  | 1 | 1113 ACSR |  |  |  |  |  |  |
22 | 230 KV WOOD STRUCTURES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
23 | YATES | BONAIRE | 230.00 | 230.00 | Wood H-Frame | 101.38 |  | 1 | 1033 ACSR | 462,785 | 22,508,948 | 22,971,733 |  |  |  |
24 | MORGANVILLE | TVA 230KV LN | 161.00 | 230.00 | Wood H-Frame | 0.13 |  | 1 | 477 ACSR |  | 25,910 | 25,910 |  |  |  |
25 | S BAINBRIDGE | FLA ST LN 230 KV LN | 230.00 | 230.00 | Wood H-Frame | 0.09 |  | 1 | 1033 ACSR | 1,289 | 14,340 | 15,629 |  |  |  |
26 | 230 KV STEEL STRUCTURES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
27 | AUGUSTA | NEWSPRINT 230 KV LOOP LN | 230.00 | 230.00 | Steel H-Frame | 8.68 |  | 1 | 1351 ACSR | 385,781 | 4,704,120 | 5,089,901 |  |  |  |
28 | AUSTIN DRIVE | SCOTTDALE 230 KV LN | 230.00 | 230.00 | Steel Pole | 11.69 |  | 1 | 1351 ACSR | 309,496 | 7,907,506 | 8,217,002 |  |  |  |
29 | COBB PLACE | WOODSTOCK 230 KV LN | 230.00 | 230.00 | Steel Pole | 10.13 |  | 1 | 1351 ACSR | 1,262,386 | 3,593,690 | 4,856,076 |  |  |  |
30 | BOAT ROCK | ADAMSVILLE 230 KV LN | 230.00 | 230.00 | Steel Single Pole | 7.23 |  | 1 | 1033 ACSR | 183,381 | 4,681,907 | 4,865,288 |  |  |  |
31 | BONAIRE | NORTH TIFTON 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 77.10 |  | 1 | 795 ACSR | 172,652 | 13,571,892 | 13,744,544 |  |  |  |
32 | BOULEVARD | BUCKHEAD | 230.00 | 230.00 | Steel Pole | 3.88 |  | 1 | 1351 SSAC | 286,289 | 1,879,613 | 2,165,902 |  |  |  |
33 | BUCKHEAD | BULL SLUICE | 230.00 | 230.00 | Steel Pole | 10.17 |  | 1 | 1351 ACSR | 750,401 | 4,926,717 | 5,677,118 |  |  |  |
34 | BOWEN | CARTERSVILLE | 230.00 | 230.00 | Steel Tower | 8.06 | 7.30 | 2 | 795 ACSR | 418,376 | 2,515,252 | 2,933,628 |  |  |  |
35 | BOWEN | PINSON | 230.00 | 230.00 | Steel H-Frame | 6.62 |  | 2 | 795 ACSR | 343,629 | 2,065,877 | 2,409,506 |  |  |  |
36 | BOWEN | PINSON-ATLANTIC STEEL 230 K | 230.00 | 230.00 | Steel H-Frame | 19.77 |  | 1 | 795 ACSR | 298,850 | 4,061,789 | 4,360,639 |  |  |  |
37 | BRANCH | EVANS 230 LINE |  |  |  |  |  |  |  |  | 3,134 | 3,134 |  |  |  |
38 | BRANCH | GOSHEN 230KV LN | 230.00 | 230.00 | Steel H-Frame | 6.61 |  | 1 | 1351 ACSR |  | 963,616 | 963,616 |  |  |  |
39 | BRANCH | PORTERDALE | 230.00 | 230.00 | Steel H-Frame | 53.01 |  | 1 | 1351 ACSR | 750,975 | 10,614,527 | 11,365,502 |  |  |  |
40 | KLONDIKE | MORROW | 230.00 | 230.00 | Steel H-Frame | 20.18 |  | 1 | 1351 ACSR | 285,883 | 4,040,769 | 4,326,652 |  |  |  |
41 | GRADY | KLONDIKE | 230.00 | 230.00 | Steel H-Frame | 0.40 |  | 1 | 795 ACSR | 5,667 | 80,095 | 85,762 |  |  |  |
42 | KLONDIKE | PORTERDALE | 230.00 | 230.00 | Steel Tower | 13.43 |  | 1 | 1351 ACSR | 190,258 | 2,689,174 | 2,879,432 |  |  |  |
43 | GRADY | KLONDIKE | 230.00 | 230.00 | Steel Tower | 5.60 |  | 1 | 795 ACSR | 79,333 | 1,121,323 | 1,200,656 |  |  |  |
44 | BRANCH | NORCROSS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 77.65 |  | 1 | 1351 ACSR | 473,871 | 10,883,719 | 11,357,590 |  |  |  |
45 | BRANCH | WINDER 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 66.37 |  | 1 | 1351 ACSR | 266,473 | 8,821,860 | 9,088,333 |  |  |  |
46 | CARTERS DAM | COOSAWATTEE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 0.46 |  | 1 | 1033 ACSR |  | 227,859 | 227,859 |  |  |  |
47 | CENTER | EAST WATKINSVILLE 230 |  |  |  |  |  |  |  |  | 140,656 | 140,656 |  |  |  |
48 | E DALTON | NORCROSS 230 KV LN | 230.00 | 230.00 | Steel Pole | 0.26 |  | 1 | 1351 ACSR | 4,981 | 56,592 | 61,573 |  |  |  |
49 | ALPHARETTA | OCEE | 230.00 | 230.00 | Steel H-Frame | 5.46 |  | 1 | 1351 ACSR | 104,611 | 1,188,438 | 1,293,049 |  |  |  |
50 | CARTERS DAM | EAST DALTON | 230.00 | 230.00 | Steel H-Frame | 19.57 |  | 1 | 1033 ACSR | 374,953 | 4,259,657 | 4,634,610 |  |  |  |
51 | MCGRAU | FORD LOOP | 230.00 | 230.00 | Steel H-Frame | 1.97 | 1.65 | 2 | 2-795 ACSR | 37,744 | 428,795 | 466,539 |  |  |  |
52 | NELSON | OCEE | 230.00 | 230.00 | Steel H-Frame | 30.61 |  | 1 | 1033 ACSR | 586,475 | 6,662,652 | 7,249,127 |  |  |  |
53 | NORCROSS | OCEE | 230.00 | 230.00 | Steel H-Frame | 10.86 |  | 1 | 1033 ACSR | 208,073 | 2,363,816 | 2,571,889 |  |  |  |
54 | E. DALTON | OOSTANAULA-PINSON 230KV | 230.00 | 230.00 | Steel H-Frame | 11.41 |  | 1 | 795 ACSR | 31,480 | 3,226,284 | 3,257,764 |  |  |  |
55 | EVANS | DUM JON 230 KV LN | 230.00 | 230.00 | Steel Pole | 34.11 |  | 1 | 1351 ACSR | 4,321,459 | 31,914,920 | 36,236,379 |  |  |  |
56 | FARLEY | SOUTH BAINBRIDGE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 53.40 |  | 1 | 1351 ACSR | 860,609 | 10,435,169 | 11,295,778 |  |  |  |
57 | FORREST RD | S MACON 230KV LN |  |  |  |  |  |  |  |  | 37,607 | 37,607 |  |  |  |
58 | FORTSON | EAST COLUMBUS 230 KV |  |  |  |  |  |  |  | 26,020 | 384,389 | 410,409 |  |  |  |
59 | GAINESVILLE | CENTER 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 22.91 |  | 1 | 1351 ACSR | 538,883 | 5,141,598 | 5,680,481 |  |  |  |
60 | GAINESVILLE | CENTER 230 KV LN | 230.00 | 230.00 | Steel Pole | 9.46 |  | 1 | 795 ACSR | 222,516 | 2,123,069 | 2,345,585 |  |  |  |
61 | GOAT ROCK | BONAIRE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 9.93 |  | 1 | 795 ACSR | 17,918 | 5,854,406 | 5,872,324 |  |  |  |
62 | GOAT ROCK | NORTH TIFTON 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 9.93 |  | 1 | 795 ACSR | 20,585 | 4,660,530 | 4,681,115 |  |  |  |
63 | GOAT ROCK | 1ST AVE COLS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 10.67 |  | 2 | 795 ACSR | 43,273 | 3,726,402 | 3,769,675 |  |  |  |
64 | GOAT ROCK | 1ST AVE COLUMBUS #2 230 KV | 230.00 | 230.00 | Steel Tower |  | 0.92 | 2 | ACSR |  |  |  |  |  |  |
65 | GOAT ROCK | 1ST AVE COLUMBUS #2 230 KV | 230.00 | 230.00 | Steel H-Frame | 9.74 |  | 1 | 1351 ACSR | 48,243 | 868,507 | 916,750 |  |  |  |
66 | SOUTH AUGUSTA | SCE&G (GRANITEVILLE) 230KV | 230.00 | 230.00 | Concrete Pole | 5.13 |  | 1 | 1351 ACSR |  | 20,387,890 | 20,387,890 |  |  |  |
67 | GOSHEN | SOUTH AUGUSTA 230 KV LN | 230.00 | 230.00 | Steel Pole | 14.83 |  | 1 | 1351 ACSR | 336,767 | 6,571,496 | 6,908,263 |  |  |  |
68 | GOSHEN | VOGTLE-WADLEY 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 47.96 |  | 1 | 795 ACSR | 498,135 | 10,300,794 | 10,798,929 |  |  |  |
69 | GRADY | WABASH-BOULEVARD 230 KV LN | 230.00 | 230.00 | Steel Pole | 3.38 |  | 1 | 1351 AAC | 707 | 3,156,044 | 3,156,751 |  |  |  |
70 | GRADY | WABASH-BOULEVARD 230 KV LN | 230.00 | 230.00 | Steel Pole | 3.69 |  | 1 | 1351 ACSR | 772 | 3,445,503 | 3,446,275 |  |  |  |
71 | HAMMOND | ALABAMA 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 11.15 |  | 1 | 1033 ACSR | 125,833 | 1,612,772 | 1,738,605 |  |  |  |
72 | HAMMOND | BOWEN NORTH 230 KV LN |  |  |  |  |  |  |  |  | 1,101,720 | 1,101,720 |  |  |  |
73 | HAMMOND | BOWEN SOUTH 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 30.28 |  | 1 | 1351 ACSR | 211,505 | 7,134,860 | 7,346,365 |  |  |  |
74 | HAMMOND | BREMEN 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 51.94 |  | 1 | 795 ACSR | 6,206,445 | 29,576,293 | 35,782,738 |  |  |  |
75 | HAMMOND | ROCK SPRINGS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 83.39 |  | 1 | 1351 ACSR | 699,833 | 21,051,194 | 21,751,027 |  |  |  |
76 | HATCH | OFFERMAN 230KV LN |  |  |  |  |  |  |  |  | 41,447 | 41,447 |  |  |  |
77 | KINGSLAND | FLA POWER & LIGHT 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 4.18 |  | 1 | 1351 ACSR | 156,797 | 2,607,741 | 2,764,538 |  |  |  |
78 | MCDONOUGH | EAST POINT 230 KV LN | 230.00 | 230.00 | Steel Tower | 12.35 | 12.38 | 1 | 1351 ACSR | 283,746 | 2,682,642 | 2,966,388 |  |  |  |
79 | MCDONOUGH | NORTHWEST #1 230 KV LN | 230.00 | 230.00 | Steel Tower | 4.59 |  | 1 | 1351 ACSR | 2,953,689 | 16,018,603 | 18,972,292 |  |  |  |
80 | MCDONOUGH | NORTHWEST #2 230 KV LN | 230.00 | 230.00 | Steel Tower |  | 4.58 | 1 | 1351 ACSR | 23,367 | 1,995,998 | 2,019,365 |  |  |  |
81 | MCDONOUGH | PEACHTREE-BLVD DC 230 KV LN | 230.00 | 230.00 | Steel Tower | 12.58 |  | 1 | 1351 ACSR | 43,454,758 | 55,933,951 | 99,388,709 |  |  |  |
82 | MITCHELL | N TIFTON 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 35.53 |  | 1 | 795 ACSR | 107,179 | 4,949,708 | 5,056,887 |  |  |  |
83 | MITCHELL | SLAPPEY DRIVE 230 KV | 115.00 | 230.00 | Steel H-Frame |  |  | 1 | 1351 ACSR | 105,970 | 1,179,619 | 1,285,589 |  |  |  |
84 | MORROW | ALABAMA STATE LINE 230 KV L | 230.00 | 230.00 | Steel H-Frame | 32.90 |  | 1 | 1351 ACSR | 40,061 | 20,476,976 | 20,517,037 |  |  |  |
85 | MORROW | ALABAMA STATE LINE 230 KV L | 230.00 | 230.00 | Steel Tower | 8.42 | 3.25 | 2 | 1351 ACSR | 10,253 | 5,240,612 | 5,250,865 |  |  |  |
86 | MORROW | ALABAMA STATE LINE 230 KV L | 230.00 | 230.00 | Steel H-Frame | 23.38 |  | 1 | 1351 ACSR | 28,469 | 14,551,723 | 14,580,192 |  |  |  |
87 | MORROW | GRADY 230 KV LN | 230.00 | 230.00 | Steel Tower |  | 9.60 | 1 | 795 ACSR |  | 2,312,672 | 2,312,672 |  |  |  |
88 | MORROW | WINDER 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 6.63 |  | 1 | 1622 ACSR | 25,150 | 2,214,478 | 2,239,628 |  |  |  |
89 | MORROW | WINDER 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 38.62 |  | 1 | 795 ACSR | 146,497 | 12,899,417 | 13,045,914 |  |  |  |
90 | N TIFTON | FLA ST LN 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 64.64 |  | 1 | 1033 ACSR | 298,930 | 5,112,165 | 5,411,095 |  |  |  |
91 | NORCROSS | MOR FALL-NO MARIETTA 230 KV | 230.00 | 230.00 | Steel Pole | 1.14 |  | 1 | 1351 ACSR | 8,161 | 386,409 | 394,570 |  |  |  |
92 | NORCROSS | MOR FALL-NO MARIETTA 230 KV | 230.00 | 230.00 | Steel Tower | 25.36 |  | 1 | 1351 ACSR | 181,550 | 8,595,913 | 8,777,463 |  |  |  |
93 | NORCROSS | SCOTTDALE-BLVD 230 KV LN | 230.00 | 230.00 | Steel Pole | 13.29 |  | 1 | 1351 ACSR | 364,041 | 2,835,913 | 3,199,954 |  |  |  |
94 | NORCROSS | SCOTTDALE-BLVD 230 KV LN | 230.00 | 230.00 | Steel Tower | 23.69 |  | 2 | 1351 ACSR | 648,919 | 5,055,138 | 5,704,057 |  |  |  |
95 | OHARA | SOUTH GRIFFIN 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 0.01 |  | 1 | 1033 ACSR |  |  |  |  |  |  |
96 | OFFERMAN | W BRUNSWICK #1 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 39.22 |  | 1 | ACSR | 131,794 | 3,920,115 | 4,051,909 |  |  |  |
97 | OFFERMAN | WEST BRUNSWICK 230 KV LN |  |  |  |  |  |  |  | 86,118 | 903,840 | 989,958 |  |  |  |
98 | PARKAIRE | PERIMETER CENTER 230 KV LN | 230.00 | 230.00 | Steel Pole | 6.08 |  | 1 | 1351 ACSR | 271,276 | 2,337,364 | 2,608,640 |  |  |  |
99 | PERIMETER CENTER | JOHNSON FY-DERING CIR | 230.00 | 230.00 | Steel Pole | 7.21 |  | 1 | 1351 ACSR | 547,901 | 4,963,482 | 5,511,383 |  |  |  |
100 | PERIMETER CENTER | JOHNSON FY-DERING CIR | 230.00 | 230.00 | UG Duct | 0.20 |  | 1 | 3000 XLPE | 15,198 | 137,683 | 152,881 |  |  |  |
101 | E DALTON | ROCK SPRINGS-TVA 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 27.90 |  | 1 | 1351 ACSR | 285,837 | 43,194,760 | 43,480,597 |  |  |  |
102 | E DALTON | ROCK SPRINGS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 15.35 |  | 1 | 1351 ACSR |  | 3,934,311 | 3,934,311 |  |  |  |
103 | RUSSELL DAM | E. WATKINSVILLE 230 KV LN | 230.00 | 230.00 | Steel Pole | 7.92 |  | 1 | 795 ACSR | 298,748 | 8,247,768 | 8,546,516 |  |  |  |
104 | RUSSELL DAM | E. WATKINSVILLE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 62.29 |  | 1 | 1351 ACSR | 2,349,621 | 64,867,865 | 67,217,486 |  |  |  |
105 | S BAINBRIDGE | FLA ST LN 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 32.84 |  | 1 | 1033 ACSR | 470,277 | 5,232,641 | 5,702,918 |  |  |  |
106 | SOUTH AUGUSTA | 15TH ST 230 KV | 115.00 | 230.00 | Steel Pole | 1.23 |  | 1 | 1351 ACSR | 497,580 | 9,411,909 | 9,909,489 |  |  |  |
107 | JONESBORO | STOCKBRIDGE 230KV | 230.00 | 230.00 | Steel Pole | 5.12 |  | 2 | 1351 ACSR |  | 4,056,849 | 4,056,849 |  |  |  |
108 | SOUTHALL | WINDER 230KV LN |  |  |  |  |  |  |  |  | 17,461 | 17,461 |  |  |  |
109 | STATESBORO | SAVANNAH 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 16.06 |  | 1 | 1033 ACSR | 338,213 | 1,354,032 | 1,692,245 |  |  |  |
110 | UNION CITY | EAST POINT #1 230 KV LN | 230.00 | 230.00 | Steel Tower | 11.04 |  | 1 | 1590 ACSR | 6,779 | 3,460,928 | 3,467,707 |  |  |  |
111 | UNION CITY | EAST POINT #2 230 KV LN | 230.00 | 230.00 | Steel Tower | 4.54 | 6.60 | 1 | 1590 ACSR | 51,850 | 3,699,357 | 3,751,207 |  |  |  |
112 | UNION CITY | SOUTH GRIFFIN 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 0.00 |  | 1 | 1033 ACSR |  |  |  |  |  |  |
113 | VIDALIA | W BRUNSWICK 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 100.54 |  | 1 | 1033 ACSR | 479,345 | 38,217,495 | 38,696,840 |  |  |  |
114 | VILLA RICA | EAST POINT 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 30.56 |  | 1 | 1351 ACSR | 88,651 | 13,330,769 | 13,419,420 |  |  |  |
115 | WADLEY | WADLEY VIDALIA #2 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 46.17 |  | 1 | 1351 ACSR | 11,953 | 5,133,921 | 5,145,874 |  |  |  |
116 | WADLEY | WADLEY VIDALIA #1 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 46.16 |  | 1 | 1033 ACSR | 252,047 | 6,004,535 | 6,256,582 |  |  |  |
117 | WALLACE DAM | EATONTON 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 15.63 |  | 1 | 1351 ACSR | 211,421 | 1,757,818 | 1,969,239 |  |  |  |
118 | WEST BRUNSWICK | KINGSLAND 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 35.96 |  | 1 | 1351 ACSR | 1,031,771 | 13,490,095 | 14,521,866 |  |  |  |
119 | WEST BRUNSWICK | MCMANUS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 6.21 |  | 1 | 1351 ACSR | 98,405 | 10,601,516 | 10,699,921 |  |  |  |
120 | YATES #5 | YATES #6 & #7 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 1.40 |  | 1 | 1033 ACSR |  | 2,436,624 | 2,436,624 |  |  |  |
121 | YATES | BONAIRE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 11.07 |  | 1 | 1033 ACSR | 50,533 | 2,457,823 | 2,508,356 |  |  |  |
122 | YATES | MORROW 230 KV LN | 230.00 | 230.00 | Steel Tower | 11.67 |  | 2 | 1351 ACSR | 187,143 | 1,795,447 | 1,982,590 |  |  |  |
123 | YATES | MORROW 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 23.39 |  | 1 | 1033 ACSR | 375,087 | 3,598,586 | 3,973,673 |  |  |  |
124 | MCINTOSH CT TIE 230KV | MCINTOSH CT TIE 230KV |  |  |  |  |  |  | 1033 ACSR |  | 454,038 | 454,038 |  |  |  |
125 | KINGSLAND | KINGS BAY #1 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 7.96 |  | 1 | 1351 ACSR | 535,649 | 2,939,913 | 3,475,562 |  |  |  |
126 | COLERAIN | KINGS BAY #2 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 7.87 |  | 1 | 1351 ACSR | 13,429 | 1,563,913 | 1,577,342 |  |  |  |
127 | ALPHARETTA | OLD ALABAMA RD 230 KV LN | 230.00 | 230.00 | Steel Pole | 2.95 |  | 1 | 1622 ACSR/TW | 1,204,520 | 3,480,166 | 4,684,686 |  |  |  |
128 | VOGTLE | SAVANNAH RIVER PLT (SCEG) 2 | 230.00 | 230.00 | Steel H-Frame | 3.99 |  | 1 | 1351 ACSR | 113,031 | 1,961,247 | 2,074,278 |  |  |  |
129 | BIG SHANTY | WOODSTOCK 230 KV LN |  |  |  |  |  |  |  |  | 1,579,498 | 1,579,498 |  |  |  |
130 | PONCE DE LEON | ROYAL ATL 230KV |  |  |  |  |  |  |  | 1,349,231 | 4,531,052 | 5,880,283 |  |  |  |
131 | OLD ALA | MARTINS LANDING 230KV | 230.00 | 230.00 | Steel Pole | 6.12 |  | 1 | 1622 ACSR/TW | 1,274,651 | 3,456,222 | 4,730,873 |  |  |  |
132 | NORC | SWEET BOT-SUWANEE 230KV | 230.00 | 230.00 | Steel Pole | 28.27 |  | 1 | 1622 ACSR/TW | 4,281,225 | 13,393,274 | 17,674,499 |  |  |  |
133 | NORCROSS | CEDAR VILLAGE-ROYAL ATL 230 | 230.00 | 230.00 | Steel Pole | 9.55 |  | 1 | 1622 ACSR/TW | 907,592 | 7,995,526 | 8,903,118 |  |  |  |
134 | W. MARIETTA | SMYRNA 230 KV LN | 230.00 | 230.00 | Steel Pole | 7.15 |  | 1 | 1351 ACSR | 805,018 | 5,069,870 | 5,874,888 |  |  |  |
135 | WINDER | SOUTH HALL 230 KV LN |  |  |  |  |  |  |  |  |  |  |  |  |  |
136 | WINDER | GAINESVILLE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 45.45 |  | 1 | 1033 ACSR | 130,180 | 4,758,200 | 4,888,380 |  |  |  |
137 | WINDER | NORCROSS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 12.11 | 1.22 | 1 | ACSR | 706,113 | 16,136,931 | 16,843,044 |  |  |  |
138 | WINDER | NORCROSS 230 KV LN | 230.00 | 230.00 | Steel Pole | 7.52 |  | 1 | 1622 ACSR/TW | 438,478 | 10,020,621 | 10,459,099 |  |  |  |
139 | BRANCH | EVANS 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 72.93 |  | 1 | 1351 ACSR | 240,420 | 12,494,288 | 12,734,708 |  |  |  |
140 | CENTER | MIDDLE FORK 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 26.98 |  | 1 | 1351 ACSR | 8,801,408 | 22,566,517 | 31,367,925 |  |  |  |
141 | MORROW | OHARA | 230.00 | 230.00 | Steel Pole | 12.95 |  | 1 | 1351 ACSR | 702,211 | 6,520,813 | 7,223,024 |  |  |  |
142 | THOMASTON | BARNESVILLE PRI 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 1.60 |  | 1 | 1033 ACSR | 111,492 | 646,783 | 758,275 |  |  |  |
143 | ANTHONY SHOALS | RUSSELL DAM 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 2.88 |  | 1 | 1351 ACSR | 2,648 | 1,780,489 | 1,783,137 |  |  |  |
144 | CARTERSVILLE | SOUTH ACWORTH 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 15.07 |  | 1 | 2-795 ACSR | 2,875,580 | 14,115,628 | 16,991,208 |  |  |  |
145 | CARTERSVILLE | SOUTH ACWORTH 230 KV LN | 230.00 | 230.00 | Steel Pole | 6.71 |  | 1 | 2-795 ACSR | 1,280,368 | 6,285,060 | 7,565,428 |  |  |  |
146 | CARTERSVILLE | MCGRAU FORD 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 18.50 |  | 1 | 1351 ACSR | 7,158,888 | 25,058,935 | 32,217,823 |  |  |  |
147 | CARTERSVILLE | MCGRAU FORD 230 KV LN | 230.00 | 230.00 | Steel Tower | 35.67 |  | 1 | 1351 ACSR | 13,803,110 | 48,316,336 | 62,119,446 |  |  |  |
148 | TIOGA | ELLIJAY 230 KV LN | 230.00 | 230.00 | Steel Pole | 7.62 |  | 1 | 1622 ACSR |  | 4,235,757 | 4,235,757 |  |  |  |
149 | TIOGA | ELLIJAY 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 5.00 |  | 1 | 1622 ACSR |  | 2,779,368 | 2,779,368 |  |  |  |
150 | CORNISH MOUNTAIN | PORTERDALE PRI 230 KV | 230.00 | 230.00 | Steel H-Frame | 7.40 |  | 1 | 1351 ACSR |  | 7,669,875 | 7,669,875 |  |  |  |
151 | ALBANY | SOWEGA 230 KV LN | 230.00 | 230.00 | Steel Pole | 8.98 |  | 1 | 1351 ACSR | 156,966 | 7,644,505 | 7,801,471 |  |  |  |
152 | FORTSON | TALBOT COUNTY 230 KV (SONAT | 230.00 | 230.00 | Steel Pole | 1.87 |  | 1 | 795 ACSR | 223,372 | 1,577,267 | 1,800,639 |  |  |  |
153 | Augusta 15th St | South Augusta | 230.00 | 230.00 | Steel Pole | 4.02 |  | 1 | 1351 ACSR | 12,051 | 59,634 | 71,685 |  |  |  |
154 | BLANDFORD | LITTLE OGEECHEE (WHITE) 230 | 230.00 | 230.00 | Steel Tower | 24.38 |  | 1 | 1033 ACSR | 855,216 | 10,359,307 | 11,214,523 |  |  |  |
155 | MCINTOSH | STATESBORO 230 KV (SAV) | 230.00 | 230.00 | Steel Tower | 21.87 |  | 1 | 1033 ACSR |  | 2,991,755 | 2,991,755 |  |  |  |
156 | MCINTOSH | STATESBORO 230 KV (SAV) | 230.00 | 230.00 | Steel H-Frame | 15.73 |  | 1 | 1033 ACSR |  | 2,151,820 | 2,151,820 |  |  |  |
157 | KRAFT | MCINTOSH (BLACK) 230 KV (SA | 230.00 | 230.00 | Steel Tower | 16.23 |  | 1 | 1622 ACCR | 260,863 | 19,177,595 | 19,438,458 |  |  |  |
158 | BLANDFORD | MCINTOSH (BLACK) 230 KV (SA | 230.00 | 230.00 | Steel Tower | 8.23 |  | 1 | 1033 ACSR |  | 8,889,253 | 8,889,253 |  |  |  |
159 | WEST MCINTOSH | MCINTOSH (BLACK) 230 KV LN | 230.00 | 230.00 | Steel Tower | 0.42 |  | 1 | 1351 ACSR |  | 1,650,320 | 1,650,320 |  |  |  |
160 | DEAN FOREST | KRAFT 230 KV (SAV) | 230.00 | 230.00 | Steel Tower | 6.01 |  | 1 | 959 ACSS | 2,286 | 6,944,481 | 6,946,767 |  |  |  |
161 | BLANDFORD | LITTLE OGEECHEE (BLACK) 230 | 230.00 | 230.00 | Steel Tower | 24.33 |  | 1 | 1033 ACSR |  | 12,110,165 | 12,110,165 |  |  |  |
162 | HOMELAND | KETTLE CREEK 230 KV | 230.00 | 230.00 | Steel Pole | 37.13 |  | 1 | 1351 ACSR | 1,635,888 | 25,643,927 | 27,279,815 |  |  |  |
163 | MCINTOSH CC 230 KV TIE LINE | MCINTOSH CC 230 KV TIE LINE | 230.00 | 230.00 | Steel Tower | 1.27 |  | 1 | 1351 ACSR |  | 2,925,832 | 2,925,832 |  |  |  |
164 | BLANDFORD | MCINTOSH (WHITE) 230 KV (SA | 230.00 | 230.00 | Steel Tower | 8.23 |  | 1 | 1033 ACSR |  | 8,187,435 | 8,187,435 |  |  |  |
165 | DORCHESTER | LITTLE OGEECHEE 230 KV LN | 230.00 | 230.00 | Steel H-Frame | 21.90 |  | 1 | 1351 ACSR | 2,410,129 | 17,274,055 | 19,684,184 |  |  |  |
166 | KRAFT | MCINTOSH (WHITE) 230 KV (SA | 230.00 | 230.00 | Steel Tower | 16.25 |  | 1 | 1033 ACSR |  | 14,289,130 | 14,289,130 |  |  |  |
167 | MCINTOSH | MCINTOSH COAL 230 KV LN | 230.00 | 230.00 | Steel Tower | 0.00 |  | 1 | 795 ACSR |  | 14,767 | 14,767 |  |  |  |
168 | MCINTOSH | MCINTOSH CT 230 KV LN | 230.00 | 230.00 | Concrete Three-Pole | 0.42 |  | 1 | 1033 ACSR |  | 22,740 | 22,740 |  |  |  |
169 | MCINTOSH | PURRYSBURG (SPSCA) 230 KV ( | 230.00 | 230.00 | Steel H-Frame | 1.98 |  | 1 | 1272 ACSR |  | 872,912 | 872,912 |  |  |  |
170 | MCINTOSH | WEST MCINTOSH (WHITE) 230 K | 230.00 | 230.00 | Concrete Pole | 0.40 |  | 1 | 1351 ACSS |  | 661,447 | 661,447 |  |  |  |
171 | BOWEN | MCCONNENELL ROAD 230KV | 230.00 | 230.00 | Steel H-Frame | 1.61 |  | 1 | 795 ACSR |  | 100,584 | 100,584 |  |  |  |
172 | BOWEN | MCCONNENELL ROAD 230KV | 230.00 | 230.00 | Steel Tower | 8.52 |  | 1 | 1113 ACSR |  | 532,286 | 532,286 |  |  |  |
173 | MCDONOUGH CC #4 TIE LINE | MCDONOUGH CC #4 TIE LINE | 230.00 | 230.00 | Steel Pole | 0.83 |  | 1 | 1113 ACSR |  | 1,956,857 | 1,956,857 |  |  |  |
174 | MCDONOUGH CC #5 TIE LINE | MCDONOUGH CC #5 TIE LINE | 230.00 | 230.00 | Steel Pole | 0.77 |  | 1 | 795 ACSR |  | 1,471,171 | 1,471,171 |  |  |  |
175 | JACK MCDONOUGH | SMYRNA 230 KV | 230.00 | 230.00 | Steel Pole | 6.93 |  | 1 | 1351 ACSR | 4,616,729 | 22,377,561 | 26,994,290 |  |  |  |
176 | MCDONOUGH CC #6 230 KV TIE LINE | MCDONOUGH CC #6 230 KV TIE LINE | 230.00 | 230.00 | Steel Pole | 0.34 |  | 1 | 1351 ACSR |  | 987,897 | 987,897 |  |  |  |
177 | VOGTLE 3&4 RAT A | VOGTLE SWITCHING 230-KV | 230.00 | 230.00 | Steel Pole | 1.02 |  | 1 | 795 ACSR |  | 1,220,828 | 1,220,828 |  |  |  |
178 | VOGTLE 3&4 230KV RAT B LINE | VOGTLE 3&4 230KV RAT B LINE | 230.00 | 230.00 | Steel Pole | 0.70 |  | 1 | 795 ACSR |  | 712,239 | 712,239 |  |  |  |
179 | CROSSGATE | DEAN FOREST 230KV | 230.00 | 230.00 | Steel Pole | 5.50 |  | 1 | 1351 ACSS | 3,043,377 | 10,597,521 | 13,640,898 |  |  |  |
180 | BOULEVARD | DEAN FOREST 230KV | 230.00 | 230.00 | Steel Pole | 4.00 |  | 1 | 1351 ACSS |  | 8,459,718 | 8,459,718 |  |  |  |
181 | THORNTON RD | TRIBUTARY 230KV | 230.00 | 231.00 | Steel Pole | 2.80 |  | 1 | 1351 ACSS | 1,796,263 | 7,530,173 | 9,326,436 |  |  |  |
182 | WANSLEY SCRUBBER 230 KV TIE | WANSLEY SCRUBBER 230 KV TIE | 230.00 | 230.00 | Concrete Pole | 2.00 |  | 1 | 1351 ACSR |  |  |  |  |  |  |
183 | PLANT BOWEN SCRUBBER TIE LINE UNIT 1 & 2 | PLANT BOWEN SCRUBBER TIE LINE UNIT 1 & 2 | 230.00 | 230.00 | Concrete Pole | 0.30 |  | 1 | 795 ACSR |  |  |  |  |  |  |
184 | HATCH SAT 1E SERVICE 230KV LINE | HATCH SAT 1E SERVICE 230KV LINE | 230.00 | 230.00 | Steel H-Frame | 0.23 |  | 1 | 795 ACSR |  | 1,483,050 | 1,483,050 |  |  |  |
185 | HATCH SAT 2E SERVICE 230KV LINE | HATCH SAT 2E SERVICE 230KV LINE | 230.00 | 230.00 | Steel Pole | 0.19 |  | 1 | 1351 ACSR |  | 233,167 | 233,167 |  |  |  |
186 | 230 KV Underground |  | 230.00 |  | VAR | 0.20 | 0.00 |  |  |  | 7,766,569 | 7,766,569 |  |  |  |
187 | 115 KV Underground |  | 115 |  | VAR | 12 | 0 |  |  |  | 23,227,403 | 23,227,403 |  |  |  |
188 | 115 KV Overhead Wood Lines |  | 115.00 |  | VAR | 4,673.68 | 32.68 |  |  | 410,323 | 5,601,353 | 6,011,676 |  |  |  |
189 | 115 KV Overhead Steel Lines |  | 115.00 |  | VAR | 1,056.62 | 80.94 |  |  | 159,943,044 | 2,183,394,813 | 2,343,337,857 |  |  |  |
190 | 69 KV Wood Lines |  | 69.00 |  | VAR | 83.54 | 23.04 |  |  | 1,608,856 | 34,335,571 | 35,944,427 |  |  |  |
191 | 69 KV Steel Lines |  | 69.00 |  | VAR | 2.79 | 0.43 |  |  | 127,202 | 2,714,688 | 2,841,890 |  |  |  |
192 | 46 KV Lines |  | 46.00 |  | VAR | 2,110.27 | 6.40 |  |  | 43,151,508 | 421,561,539 | 464,713,047 |  |  |  |
36 | TOTAL |  |  |  |  | 11,629.94 | 202.72 | 177 |  | 405,740,523.00 | 4,277,672,899.00 | 4,683,413,422.00 | 0.00 | 0.00 | 0.00 | 0.00

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSMISSION LINES ADDED DURING YEAR
Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m). If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
| LINE DESIGNATION |  | SUPPORTING STRUCTURE | CIRCUITS PER STRUCTURE | CONDUCTORS |  | LINE COST |
Line No. | TransmissionLineStartPoint From | TransmissionLineEndPoint To | LengthOfTransmissionLineAdded Line Length in Miles | SupportingStructureOfTransmissionLineType Type | AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles | NumberOfTransmissionCircuitsPerStructurePresent Present | NumberOfTransmissionCircuitsPerStructureUltimate Ultimate | ConductorSize Size | ConductorSpecification Specification | ConductorConfigurationAndSpacing Configuration and Spacing | OperatingVoltageOfTransmissionLine Voltage KV (Operating) | CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights | CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures | CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices | Asset Retire. Costs | CostOfTransmissionLinesAdded Total | SupportingStructureConstructionType Construction
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) | (k) | (l) | (m) | (n) | (o) | (p) | (q)
1 | VOGTLE 3&4 | 230 KV RAT A LINE | 0.85 | SSP | 10.00 | 1 | 1 | 795 | ACSR | 1/PHASE | 230 |  | 976,730 | 244,098 |  | 1,220,828 | Overground
2 | FIFTEENTH STREET 042568 | VERDERY STREET 115 KV | 0.02 | SSP | 10.00 | 1 | 1 | 762 | ACSR | 1/PHASE | 115 |  | 813,806 | 332,101 | 4,519 | 1,141,388 | Overground
3 | ATLANTA WATER STORAGE (LOIS ST) | NORTHWEST 115 KV | 0.13 | SSP | 10.00 | 1 | 1 | 1351 | ACSR | 1/PHASE | 115 |  | 1,103,099 | 104,170 | 106,604 | 1,100,665 | Overground
4 | TUGALO | YONAH 115 KV | 0.31 | SSP | 10.00 | 1 | 1 | 4/0 | ACSR | 1/PHASE | 115 |  | 5,534,468 | 5,103,606 | 38,761 | 10,599,313 | Overground
44 | TOTAL |  | 0.65 |  | 40.00 | 4 | 4 |  |  |  |  |  | 8,428,103 | 5,783,975 | 149,884 | 14,062,194 |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
|  | Character of Substation | VOLTAGE (In MVa) |  |  |  | Conversion Apparatus and Special Equipment
Line No. | SubstationNameAndLocation Name and Location of Substation (a) | SubstationCharacterDescription Transmission or Distribution (b) | SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1) | PrimaryVoltageLevel Primary Voltage (In MVa) (c) | SecondaryVoltageLevel Secondary Voltage (In MVa) (d) | TertiaryVoltageLevel Tertiary Voltage (In MVa) (e) | SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f) | NumberOfTransformersInService Number of Transformers In Service (g) | Number of Spare Transformers (h) | ConversionApparatusAndSpecialEquipmentType Type of Equipment (i) | NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j) | CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1 | 1 ABBEVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
2 | 2 ABCD FARMS PM | Distribution | Unattended | 46.00 | 12.00 |  |  | 1 |  |  |  |
3 | 3 ABCD FARMS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
4 | 4 ACORN CREEK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
5 | 5 ACWORTH | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
6 | 6 ADAIRSVILLE | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
7 | 7 ADAMS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
8 | 8 ADDLESTONE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
9 | 9 AERO COMMANDER | Distribution | Unattended | 12.00 | 0.48 |  | 1.68 | 1 |  |  |  |
10 | 10 AINSLIE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
11 | 11 AIR PRODUCTS AND CHEMICALS | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
12 | 12 AIRGAS (Pendergrass) | Distribution | Unattended | 230.00 | 4.00 |  | 50.00 | 2 |  |  |  |
13 | 13 AIRGAS (Pendergrass) | Distribution | Unattended | 230.00 | 25.00 |  | 40.00 | 1 |  |  |  |
14 | 14 AIRLINE | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 34,800
15 | 15 AIRPORT ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
16 | 16 ALADDIN FIBER ONE #1 PD | Distribution | Unattended | 46.00 | 0.48 |  | 3.75 | 1 |  |  |  |
17 | 17 ALADDIN FIBER ONE #2 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 | 1 |  |  |
18 | 18 ALADDIN FIBER ONE #2 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 | 1 |  |  |
19 | 19 ALADDIN FIBER ONE #6 PD | Distribution | Unattended | 46.00 | 0.48 |  | 3.75 | 1 |  |  |  |
20 | 20 ALADDIN FIBER ONE #7 PD | Distribution | Unattended | 46.00 | 0.48 |  | 3.75 | 1 |  |  |  |
21 | 21 ALADDIN FIBER ONE #8 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
22 | 22 ALADDIN MILLS | Distribution | Unattended | 46.00 | 0.48 |  | 10.50 | 2 |  |  |  |
23 | 23 ALADDIN MILLS #2 | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 1 |  |  |  |
24 | 24 ALADDIN MILLS #2 | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
25 | 25 ALADDIN MILLS #3 | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
26 | 26 ALADDIN MILLS #3 | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
27 | 27 ALADDIN MILLS (Forsyth) | Distribution | Unattended | 12.00 | 0.60 |  | 3.50 | 1 |  |  |  |
28 | 28 ALAPAHA | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
29 | 29 ALCOVY ROAD | Transmission | Unattended | 115.00 | 46.00 |  | 56.00 | 1 |  |  |  |
30 | 30 ALCOVY ROAD | Transmission | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
31 | 31 ALDORA MILLS #3 | Distribution | Unattended | 69.00 | 4.00 |  | 25.00 | 1 |  |  |  |
32 | 32 ALEXANDER DRIVE | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
33 | 33 ALKEN-ZEIGLER | Distribution | Unattended | 46.00 | 0.48 |  | 0.50 | 1 |  |  |  |
34 | 34 ALLATOONA HEIGHTS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
35 | 35 ALLEN ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
36 | 36 ALPHARETTA | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
37 | 37 ALTAMAHA BOULEVARD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 30,000
38 | 38 ALTO | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
39 | 39 ALTO | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
40 | 40 AMERICAN GRANITE QUARRIES | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 3 |  |  |  |
41 | 41 AMERICUS | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 45,900
42 | 42 AMERICUS | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  |  |  |
43 | 43 AMERICUS | Transmission | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
44 | 44 AMHERST | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
45 | 45 ANCHOR GLASS | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
46 | 46 ANCHOR GLASS | Distribution | Unattended | 115.00 | 12.00 |  | 10.00 | 1 |  |  |  |
47 | 47 ANDERSONVILLE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
48 | 48 ANGLO AMERICAN CLAY TEMPORARY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
49 | 49 ANGLO AMERICAN CLAY TEMPORARY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
50 | 50 ANTHONY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
51 | 51 ANTHONY PM | Distribution | Unattended | 46.00 | 12.00 |  |  | 2 |  |  |  |
52 | 52 ANTIOCH ROAD | Distribution | Unattended | 115.00 | 46.00 |  | 40.00 | 1 |  |  |  |
53 | 53 ANTIOCH ROAD | Distribution | Unattended | 115.00 | 46.00 |  | 60.00 | 1 |  |  |  |
54 | 54 ANTIOCH ROAD | Distribution | Unattended | 46.00 | 12.00 |  | 8.40 | 2 |  |  |  |
55 | 55 APAC (Camak) | Distribution | Unattended | 46.00 | 25.00 |  | 14.00 | 2 |  |  |  |
56 | 56 APALACHEE AREA #1 PM (RETIRED) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
57 | 57 AQUILLA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
58 | 58 AQUILLA | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
59 | 59 ARAGON | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
60 | 60 ARAGON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 1 | 10,800
61 | 61 ARBOR | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
62 | 62 ARCHER DANIELS MIDLAND (Valdosta) | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 1 | 3,600
63 | 63 ARGOS (Atlanta) | Distribution | Unattended | 115.00 | 4.00 |  | 14.00 | 2 |  |  |  |
64 | 64 ARLINGTON | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
65 | 65 ARMSTRONG GLASS (Jasper) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 3 |  |  |  |
66 | 66 ARMSTRONG WORLD INDUSTRIES | Distribution | Unattended | 115.00 | 4.00 |  | 134.40 | 4 |  |  |  |
67 | 67 ARMUCHEE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
68 | 68 ARTESIAN STREET | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 8
69 | 69 ASAMA COLDWATER MANUFACTURING | Distribution | Unattended | 115.00 | 13.80 |  | 44.80 | 2 |  | Capacitor Bank | 2 | 4,800
70 | 70 ASAMA COLDWATER MANUFACTURING | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
71 | 71 ASHBURN PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
72 | 72 ASHBURN PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
73 | 73 ASHFORD | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
74 | 74 ATHENA | Distribution | Unattended | 115.00 | 25.00 |  | 100.00 | 2 |  | Capacitor Bank | 2 | 90,000
75 | 75 ATHENS | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 2 | 78,900
76 | 76 ATHENS OPERATING PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
77 | 77 ATHENS OPERATING PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
78 | 78 ATHENS PUMPING | Distribution | Unattended | 46.00 | 4.00 |  | 7.00 | 1 |  |  |  |
79 | 79 ATLANTA FULTON COUNTY WATER TREATMENT | Distribution | Unattended | 230.00 | 12.00 |  | 67.20 | 2 |  |  |  |
80 | 80 ATLANTA WATER STORAGE (Lois Street) | Distribution | Unattended | 115.00 | 4.00 |  | 50.00 | 2 |  |  |  |
81 | 81 ATLANTA WATER TREATMENT (Bolton) | Distribution | Unattended | 115.00 | 4.00 |  | 50.00 | 2 |  |  |  |
82 | 82 ATLANTA WATER TREATMENT (Bolton) | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
83 | 83 ATLANTA WATER WORKS (Adamsville) | Distribution | Unattended | 46.00 | 4.00 |  | 1.68 | 3 |  |  |  |
84 | 84 ATLANTA WATER WORKS (Moores Mill) | Distribution | Unattended | 20.00 | 2.40 |  | 2.00 | 3 |  |  |  |
85 | 85 ATLANTIC DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
86 | 86 ATTAPULGUS | Distribution | Unattended | 25.00 | 4.00 |  | 7.00 | 1 |  |  |  |
87 | 87 ATTAPULGUS | Distribution | Unattended | 25.00 | 4.00 |  | 7.00 | 1 |  |  |  |
88 | 88 AUGUSTA AREA #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
89 | 89 AUGUSTA AREA #4 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
90 | 90 AUGUSTA CORPORATE PARK | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
91 | 91 AUGUSTA NEWSPRINT | Distribution | Unattended | 230.00 | 13.80 |  | 224.00 | 4 | 1 |  |  |
92 | 92 AUSTELL | Distribution | Unattended | 115.00 | 25.00 |  | 33.33 | 1 |  | Capacitor Bank | 2 | 60,000
93 | 93 AUSTELL | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
94 | 94 AUSTELL | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
95 | 95 AUSTELL BOX BOARD | Distribution | Unattended | 46.00 | 0.60 |  | 14.00 | 2 |  |  |  |
96 | 96 AUSTIN DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  | Capacitor Bank | 1 | 120,000
97 | 97 AUTREY FURNITURE | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
98 | 98 AVONDALE MILL ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
99 | 99 AVONLEA | Distribution | Unattended | 230.00 | 25.00 |  | 120.00 | 2 |  |  |  |
100 | 100 BAINBRIDGE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
101 | 101 BAINBRIDGE | Distribution | Unattended | 115.00 | 12.00 |  | 47.04 | 2 |  |  |  |
102 | 102 BAKER PLACE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
103 | 103 BAKER PLACE | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
104 | 104 BAKERS FERRY ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
105 | 105 BALDWIN | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
106 | 106 BALDWIN | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
107 | 107 BANNING LAKE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
108 | 108 BARCO #1 (TALLAPOOSA) PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
109 | 109 BARNESVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 48,900
110 | 110 BARNETT ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
111 | 111 BARTLETTS FERRY | Transmission | Unattended | 14.40 | 0.48 |  | 1.12 | 3 |  |  |  |
112 | 112 BARTLETTS FERRY | Transmission | Unattended | 115.00 | 6.60 |  | 30.00 | 1 |  |  |  |
113 | 113 BARTLETTS FERRY | Transmission | Unattended | 115.00 | 12.00 |  | 130.00 | 1 |  |  |  |
114 | 114 BARTLETTS FERRY | Transmission | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
115 | 115 BARTLETTS FERRY | Transmission | Unattended | 13.80 | 0.48 |  | 2.24 | 2 |  |  |  |
116 | 116 BARTON CHAPEL | Distribution | Unattended | 230.00 | 12.00 |  | 33.60 | 1 |  |  |  |
117 | 117 BARTOW | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 3 | 1 |  |  |
118 | 118 BASE MANUFACTURING | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
119 | 119 BASSETT FURNITURE | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
120 | 120 BATH | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
121 | 121 BATTLECREEK | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
122 | 122 BAXLEY | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 60,000
123 | 123 BAXLEY | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
124 | 124 BAXLEY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
125 | 125 BAYER CROPSCIENCE | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
126 | 126 BEASLEY TIMBER | Distribution | Unattended | 46.00 | 0.48 |  | 3.36 | 2 |  |  |  |
127 | 127 BEASLEY TIMBER #2 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
128 | 128 BEAULIEU AMERICA (Royston) | Distribution | Unattended | 46.00 | 0.60 |  | 3.86 | 2 |  |  |  |
129 | 129 BEAVER DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
130 | 130 BEAVER DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
131 | 131 BEAVERS ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
132 | 132 BEKAERT STEEL WIRE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
133 | 133 BELAIR | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
134 | 134 BELL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
135 | 135 BELLEVUE | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
136 | 136 BELVEDERE | Distribution | Unattended | 20.00 | 12.00 |  | 22.40 | 1 |  |  |  |
137 | 137 BELVEDERE | Distribution | Unattended | 115.00 | 20.00 |  | 41.60 | 1 |  |  |  |
138 | 138 BELVEDERE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
139 | 139 BEN HILL | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
140 | 140 BENDIX FRICTION MATERIALS | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
141 | 141 BERCKMAN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
142 | 142 BERKELEY LAKE | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
143 | 143 BERKELEY LAKE | Distribution | Unattended | 230.00 | 25.00 |  | 33.60 | 1 |  |  |  |
144 | 144 BERKELEY LAKE | Distribution | Unattended | 230.00 | 25.00 |  | 50.00 | 1 |  |  |  |
145 | 145 BETHLEHEM 115/25-KV | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
146 | 146 BEULAH PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
147 | 147 BIBB MANUFACTURING (Percale) | Distribution | Unattended | 115.00 | 4.00 |  | 14.00 | 2 |  |  |  |
148 | 148 BICKERSTAFF CLAY PRODUCTS | Distribution | Unattended | 20.00 | 0.60 |  | 2.50 | 3 |  |  |  |
149 | 149 BIG A | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
150 | 150 BIG CREEK SEWAGE TREATMENT | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
151 | 151 BIG CREEK SEWAGE TREATMENT | Distribution | Unattended | 20.00 | 12.00 |  | 44.80 | 2 |  |  |  |
152 | 152 BIG POPLAR | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
153 | 153 BIG POPLAR | Distribution | Unattended | 25.00 | 12.00 |  | 10.50 | 1 |  |  |  |
154 | 154 BIG POPLAR SPRINGS ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
155 | 155 BILL FRANKS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
156 | 156 BLACK BEAR PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
157 | 157 BLACK CREEK | Distribution | Unattended | 115.00 | 13.80 |  | 14.00 | 1 |  |  |  |
158 | 158 BLACKSHEAR | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
159 | 159 BLACKSMITH | Transmission | Unattended | 500.00 |  |  |  | 3 | 1 |  |  |
160 | 160 BLACKWELLS | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
161 | 161 BLAKELY PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 60,000
162 | 162 BLANCHARD INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
163 | 163 BLEYLE AMERICA | Distribution | Unattended | 25.00 | 0.48 |  | 1.68 | 1 |  |  |  |
164 | 164 BLOOMFIELD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
165 | 165 BLOOMFIELD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
166 | 166 BLOOMINGDALE | Distribution | Unattended | 46.00 | 13.80 |  | 10.50 | 1 |  |  |  |
167 | 167 BLOOMINGDALE | Distribution | Unattended | 46.00 | 13.80 |  | 14.00 | 1 |  |  |  |
168 | 168 BLOSSOM CREEK | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
169 | 169 BLUE CIRCLE AGGREGATES #1 (Lithonia) | Distribution | Unattended | 46.00 | 0.60 |  | 2.50 | 3 |  |  |  |
170 | 170 BLUE RIDGE MOUNTAIN WOODCRAFT | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 3 |  |  |  |
171 | 171 BOAT ROCK ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
172 | 172 BOAT ROCK ROAD | Distribution | Unattended | 20.00 | 12.00 |  | 22.40 | 1 |  |  |  |
173 | 173 BOBBY JONES | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
174 | 174 BOBBY JONES | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
175 | 175 BOGART | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
176 | 176 BOJO | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
177 | 177 BOJO | Distribution | Unattended | 115.00 | 25.00 |  | 21.00 | 2 |  |  |  |
178 | 178 BOLIVAR | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
179 | 179 BOLLING ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
180 | 180 BOLTON | Distribution | Unattended | 115.00 | 20.00 |  | 46.67 | 1 |  |  |  |
181 | 181 BOLTON | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
182 | 182 BOLTON STREET | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
183 | 183 BOLTON STREET | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
184 | 184 BONANZA | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
185 | 185 BONANZA | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
186 | 186 BONE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
187 | 187 BORAL BRICK | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
188 | 188 BOSTON | Distribution | Unattended | 69.00 | 12.00 |  | 7.00 | 1 |  |  |  |
189 | 189 BOULEVARD (Atlanta) | Transmission | Unattended | 115.00 | 20.00 |  | 112.00 | 2 |  | Capacitor Bank | 2 | 117,000
190 | 190 BOULEVARD (Atlanta) | Transmission | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
191 | 191 BOULEVARD (Savannah) | Transmission | Unattended | 115.00 | 13.80 |  | 37.21 | 1 |  | Capacitor Bank | 1 | 60,000
192 | 192 BOWDON JUNCTION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
193 | 193 BOWEN | Generation | Attended | 230.00 | 25.00 |  | 900.00 | 3 |  |  |  |
194 | 194 BOWEN | Generation | Attended | 25.00 | 13.80 |  | 140.00 | 2 |  |  |  |
195 | 195 BOWEN | Generation | Attended | 25.00 | 4.00 |  | 20.00 | 1 |  |  |  |
196 | 196 BOWEN | Generation | Attended | 500.00 | 25.00 |  | 900.00 | 3 |  |  |  |
197 | 197 BOWEN | Generation | Attended | 230.00 | 4.00 |  | 25.00 | 1 |  |  |  |
198 | 198 BOWEN | Generation | Attended | 25.00 | 4.00 |  | 67.20 | 3 |  |  |  |
199 | 199 BOWEN | Generation | Attended | 230.00 | 13.80 |  | 115.00 | 2 |  |  |  |
200 | 200 BOWEN | Generation | Attended | 20.00 | 4.00 |  | 44.80 | 2 |  |  |  |
201 | 201 BOWEN | Generation | Attended | 500.00 |  |  | 2052.00 | 6 |  |  |  |
202 | 202 BOWEN | Generation | Attended | 23.00 | 4.16 |  | 45.00 | 1 |  |  |  |
203 | 203 BOWEN | Generation | Attended | 25.00 | 4.00 |  | 80.00 | 2 |  |  |  |
204 | 204 BOWEN | Generation | Attended | 25.00 | 0.60 |  | 9.60 | 1 |  |  |  |
205 | 205 BOWEN | Generation | Attended | 18.00 | 4.00 |  | 40.00 | 2 |  |  |  |
206 | 206 BOWEN | Generation | Attended | 20.00 | 13.80 |  | 140.00 | 2 |  |  |  |
207 | 207 BOWEN NPDES | Distribution | Attended | 46.00 | 4.00 |  | 3.75 | 1 |  |  |  |
208 | 208 BOWEN PUMPING | Distribution | Attended | 115.00 | 4.00 |  | 22.40 | 4 |  |  |  |
209 | 209 BOWMAN | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
210 | 210 BOXWOOD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
211 | 211 BOYD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
212 | 212 BRADLEY INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
213 | 213 BRADLEY INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
214 | 214 BRENTWOOD | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
215 | 215 BRIAR VISTA | Distribution | Unattended | 115.00 | 20.00 |  | 120.00 | 2 |  |  |  |
216 | 216 BRIAR VISTA | Distribution | Unattended | 20.00 | 12.00 |  | 22.40 | 1 |  |  |  |
217 | 217 BRIDGEPORT BRASS | Distribution | Unattended | 46.00 | 0.24 |  | 5.60 | 6 |  |  |  |
218 | 218 BROAD RIVER FOREST PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
219 | 219 BROAD RIVER STONE | Distribution | Unattended | 46.00 | 25.00 |  | 7.00 | 1 |  |  |  |
220 | 220 BROADWAY | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 2 |  | Capacitor Bank | 2 | 60,000
221 | 221 BROADWAY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
222 | 222 BRODIE METER | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
223 | 223 BRONWOOD | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
224 | 224 BROOKHAVEN BOULEVARD | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
225 | 225 BROOKHAVEN BOULEVARD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 2 |  |  |  |
226 | 226 BROOKLET | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
227 | 227 BROWN AND WILLIAMSON TOBACCO | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
228 | 228 BROWN BROTHERS #2 | Distribution | Unattended | 12.00 | 2.40 |  | 2.80 | 3 |  |  |  |
229 | 229 BROWN BROTHERS SAND PIT | Distribution | Unattended | 12.00 | 2.40 |  | 7.00 | 2 |  |  |  |
230 | 230 BROWN FARM ROAD | Distribution | Unattended | 25.00 | 12.00 |  | 10.50 | 1 |  |  |  |
231 | 231 BROWN FARM ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
232 | 232 BRUNSWICK | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  | Capacitor Bank | 2 | 60,000
233 | 233 BUCKHEAD (Madison) (NEW) | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
234 | 234 BUCKHEAD PRIMARY | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
235 | 235 BUCKHEAD PRIMARY | Distribution | Unattended | 230.00 | 20.00 |  | 112.00 | 2 |  |  |  |
236 | 236 BUDWEISER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
237 | 237 BUENA VISTA | Distribution | Unattended | 46.00 | 25.00 |  | 10.50 | 2 |  |  |  |
238 | 238 BUENA VISTA | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
239 | 239 BUFFALO ROAD | Distribution | Unattended | 25.00 | 12.00 |  | 10.50 | 1 |  |  |  |
240 | 240 BUFFALO ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
241 | 241 BUFORD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 58,500
242 | 242 BUFORD | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
243 | 243 BUHLER QUALITY YARNS | Distribution | Unattended | 115.00 | 12.00 |  | 28.00 | 4 |  |  |  |
244 | 244 BULK FABRICATED PRODUCTS | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
245 | 245 BULL CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  | Capacitor Bank | 1 | 60,000
246 | 246 BULL MOOSE TUBE | Distribution | Unattended | 46.00 | 0.48 |  | 5.60 | 1 |  |  |  |
247 | 247 BURGESS PIGMENT | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
248 | 248 BURGESS PIGMENT #2 PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
249 | 249 BURKHALTER ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
250 | 250 BURNT HICKORY | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
251 | 251 BURTON | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
252 | 252 BURTON HYDRO | Generation | Attended | 46.00 | 6.60 |  | 10.50 | 1 |  |  |  |
253 | 253 BUTLER | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
254 | 254 BUTLER | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
255 | 255 BUTLER | Distribution | Unattended | 46.00 | 12.00 |  | 9.37 | 2 |  |  |  |
256 | 256 BUTLER | Distribution | Unattended | 230.00 | 46.00 |  | 33.60 | 1 |  |  |  |
257 | 257 BUTLER STREET | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
258 | 258 BUTLER STREET | Distribution | Unattended | 115.00 | 20.00 |  | 180.00 | 3 |  |  |  |
259 | 259 CADWELL PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
260 | 260 CAGLES (Perry) | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
261 | 261 CAGLES (Perry) | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
262 | 262 CALHOUN COUNTY PRISON #1 PD (East) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
263 | 263 CALHOUN COUNTY PRISON #2 PD (West) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
264 | 264 CALHOUN ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
265 | 265 CAMP JOSEY | Transmission | Unattended | 230.00 | 46.00 |  | 46.67 | 1 |  |  |  |
266 | 266 CAMP JOSEY #2 PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
267 | 267 CAMP ODOM PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
268 | 268 CANDLER AREA PM | Distribution | Unattended | 46.00 | 12.47 |  | 0.25 | 1 |  |  |  |
269 | 269 CANDLER HOSPITAL | Distribution | Unattended | 13.20 | 0.28 |  | 4.20 | 3 | 1 |  |  |
270 | 270 CANNONGATE ACRES PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
271 | 271 CANON | Distribution | Unattended | 46.00 | 12.00 |  | 3.75 | 1 |  |  |  |
272 | 272 CANTON #2 | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
273 | 273 CANYON ROAD | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
274 | 274 CARL FINDLEY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
275 | 275 CARLTON RURAL PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
276 | 276 CARMEUSE MINE #1 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.00 | 1 |  |  |  |
277 | 277 CARNESVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
278 | 278 CARPENTER FLAT | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
279 | 279 CARROLLTON | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 2 | 60,000
280 | 280 CARROLLTON #2 | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
281 | 281 CARWOOD MANUFACTURING | Distribution | Unattended | 12.00 | 0.48 |  | 2.10 | 1 |  |  |  |
282 | 282 CASCADE HEIGHTS | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
283 | 283 CASSVILLE | Distribution | Unattended | 46.00 | 25.00 |  | 10.00 | 1 |  |  |  |
284 | 284 CASTLEBERRY ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
285 | 285 CASTLEBERRY ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
286 | 286 CASTLEBERRY ROAD | Distribution | Unattended | 25.00 | 12.00 |  | 25.00 | 1 |  |  |  |
287 | 287 CAVE SPRING #2 | Distribution | Unattended | 230.00 | 12.00 |  | 25.00 | 1 |  |  |  |
288 | 288 CDC (Clifton Road) | Distribution | Unattended | 20.00 | 4.00 |  | 80.00 | 4 |  |  |  |
289 | 289 CEDAR CREEK ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
290 | 290 CEDAR HILL | Distribution | Unattended | 230.00 | 12.00 |  | 40.00 | 1 |  |  |  |
291 | 291 CEDAR SPRINGS | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
292 | 292 CEDAR SPRINGS | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
293 | 293 CEDAR VILLAGE | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
294 | 294 CEDARTOWN | Transmission | Unattended | 230.00 | 46.00 |  | 56.00 | 1 |  |  |  |
295 | 295 CELANESE | Transmission | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  | Capacitor Bank | 1 | 30,000
296 | 296 CENTRAL AVENUE | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
297 | 297 CENTRAL STATE HOSPITAL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
298 | 298 CERTAINTEED (Athens) | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
299 | 299 CERTAINTEED (Athens) | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
300 | 300 CERTAINTEED (Social Circle) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
301 | 301 CERTAINTEED (Social Circle) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
302 | 302 CHADBOURN GOTHAM | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
303 | 303 CHARLES WHITLOCK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
304 | 304 CHATHAM COUNTY INDUSTRIAL | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
305 | 305 CHATSWORTH | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
306 | 306 CHATTAHOOCHEE | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
307 | 307 CHAUNCEY | Distribution | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  |  |  |
308 | 308 CHEROKEE | Distribution | Unattended | 46.00 | 13.80 |  | 14.00 | 1 |  |  |  |
309 | 309 CHEROKEE BRICK | Distribution | Unattended | 12.00 | 0.60 |  | 5.60 | 2 |  |  |  |
310 | 310 CHEROKEE ROAD | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
311 | 311 CHEROKEE ROAD | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
312 | 312 CHICKAMAUGA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
313 | 313 CHICKAMAUGA | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
314 | 314 CHICOPEE MANUFACTURING | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
315 | 315 CHICOPEE MANUFACTURING | Distribution | Unattended | 115.00 | 12.00 |  | 18.75 | 2 |  |  |  |
316 | 316 CHICOPEE WOODS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
317 | 317 CHILDRESS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
318 | 318 CHINA HILL ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
319 | 319 CHINA HILL ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
320 | 320 CHINCHILLA ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 1.00 | 3 |  |  |  |
321 | 321 CHLORIDE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
322 | 322 CHOKEE PLANTATION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
323 | 323 CHOKEE PLANTATION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
324 | 324 CHOKEE PLANTATION #2 PM | Distribution | Unattended | 46.00 | 0.48 |  | 0.30 | 1 |  |  |  |
325 | 325 CHULA PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
326 | 326 CITGO | Distribution | Unattended | 13.20 | 2.40 |  | 2.50 | 3 |  |  |  |
327 | 327 CLARKESVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
328 | 328 CLARKESVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 9.37 | 2 |  |  |  |
329 | 329 CLARKS BRIDGE | Distribution | Unattended | 46.00 | 12.00 | 7 | 10.50 | 1 |  |  |  |
330 | 330 CLARKSTON | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
331 | 331 CLARKSTON | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
332 | 332 CLAXTON | Transmission | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  | Capacitor Bank | 2 | 60,000
333 | 333 CLAYTON | Distribution | Unattended | 115.00 | 12.00 |  | 42.00 | 4 |  |  |  |
334 | 334 CLAYTON MARCUS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
335 | 335 CLEARWATER ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
336 | 336 CLERMONT JUNCTION | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  | Capacitor Bank | 1 | 44,100
337 | 337 CLOUDLAND CANYON | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
338 | 338 CLOUDLAND CANYON | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
339 | 339 CLOVERLEAF | Distribution | Unattended | 230.00 | 12.00 |  | 33.60 | 1 |  |  |  |
340 | 340 CLYATTVILLE | Distribution | Unattended | 69.00 | 12.00 |  | 5.25 | 1 |  |  |  |
341 | 341 COAL MOUNTAIN | Distribution | Unattended | 230.00 | 25.00 |  | 40.00 | 1 |  |  |  |
342 | 342 COATS AMERICAN (Toccoa) | Distribution | Unattended | 12.00 | 4.00 |  | 3.50 | 1 |  |  |  |
343 | 343 COBB | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
344 | 344 COBB COUNTY R. L. SUTTON WRF | Distribution | Unattended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
345 | 345 COBB COUNTY R. L. SUTTON WRF | Distribution | Unattended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
346 | 346 COBB MARIETTA WATER #1 (Johnson Ferry) | Distribution | Unattended | 20.00 | 4.00 |  | 6.25 | 1 |  |  |  |
347 | 347 COBB MARIETTA WATER #2 (Johnson Ferry) | Distribution | Unattended | 20.00 | 4.00 |  | 6.25 | 1 |  |  |  |
348 | 348 COBB MARIETTA WATER (Allatoona) | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 2 |  |  |  |
349 | 349 COBB MARIETTA WATER (Lower Roswell) | Distribution | Unattended | 20.00 | 4.00 |  | 28.00 | 2 |  |  |  |
350 | 350 COBB MARIETTA WATER (Wyckoff) | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 1 |  |  |  |
351 | 351 COBB MARIETTA WATER (Wyckoff) | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 1 |  |  |  |
352 | 352 COBB PLACE | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
353 | 353 COBB PLACE | Distribution | Unattended | 230.00 | 12.00 |  | 33.60 | 1 |  |  |  |
354 | 354 COBLE DAIRY PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
355 | 355 COCA COLA (Hapeville) | Distribution | Unattended | 115.00 | 20.00 |  | 25.00 | 1 |  |  |  |
356 | 356 COCHRAN PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
357 | 357 COCHRAN PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
358 | 358 CODY ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 41.70 | 1 |  |  |  |
359 | 359 COLEMAN | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
360 | 360 COLEMAN (Savannah) | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
361 | 361 COLEMAN (Savannah) | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
362 | 362 COLONELS ISLAND | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
363 | 363 COLONELS ISLAND | Distribution | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
364 | 364 COLONIAL PIPELINE (Armuchee) | Distribution | Unattended | 115.00 | 4.00 |  | 7.00 | 1 |  |  |  |
365 | 365 COLONIAL PIPELINE (Bremen) | Distribution | Unattended | 115.00 | 4.00 |  | 18.75 | 2 |  |  |  |
366 | 366 COLONIAL PIPELINE (Bremen) | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
367 | 367 COLONIAL PIPELINE (Dacula) | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
368 | 368 COLONIAL PIPELINE (Dacula) | Distribution | Unattended | 115.00 | 4.00 |  | 21.00 | 2 |  |  |  |
369 | 369 COLONIAL PIPELINE (Danielsville) | Distribution | Unattended | 115.00 | 4.00 |  | 21.00 | 2 |  |  |  |
370 | 370 COLONIAL PIPELINE (Powder Springs) | Distribution | Unattended | 115.00 | 4.00 |  | 28.00 | 2 |  |  |  |
371 | 371 COLONIAL PIPELINE (Smyrna) | Distribution | Unattended | 115.00 | 4.00 |  | 21.00 | 2 |  |  |  |
372 | 372 COLOR IMAGE | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
373 | 373 COLQUITT | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
374 | 374 COLUMBUS | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  | Capacitor Bank | 2 | 57,600
375 | 375 COLUMBUS FOUNDRY | Distribution | Unattended | 115.00 | 12.00 |  | 56.00 | 1 |  |  |  |
376 | 376 COLUMBUS FOUNDRY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
377 | 377 COLUMBUS SEWAGE | Distribution | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  |  |  |
378 | 378 COLUMBUS SQUARE | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  |  |  |
379 | 379 COMER PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
380 | 380 COMER PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
381 | 381 COMMERCE PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 49,500
382 | 382 COMMODORE PARK | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
383 | 383 COMOLLI GRANITE | Distribution | Unattended | 46.00 | 0.48 |  | 1.12 | 1 |  |  |  |
384 | 384 CONCORD | Distribution | Unattended | 46.00 | 12.00 |  | 3.75 | 3 |  |  |  |
385 | 385 CONCORD GROVE | Distribution | Unattended | 20.00 | 12.00 |  | 25.00 | 1 |  |  |  |
386 | 386 CONCORD GROVE | Distribution | Unattended | 115.00 | 20.00 |  | 80.00 | 2 |  |  |  |
387 | 387 CONLEY CREEK | Distribution | Unattended | 115.00 | 20.00 |  | 80.00 | 2 |  |  |  |
388 | 388 CONLEY CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
389 | 389 CONLEY CREEK | Distribution | Unattended | 20.00 | 12.00 |  | 25.00 | 1 |  |  |  |
390 | 390 CONSOLIDATED MINERALS PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
391 | 391 CONTAINER CORPORATION OF AMERICA | Distribution | Unattended | 25.00 | 0.48 |  | 2.80 | 1 |  |  |  |
392 | 392 CONYERS | Transmission | Unattended | 230.00 | 46.00 |  | 40.00 | 1 |  | Capacitor Bank | 1 | 58,500
393 | 393 CONYERS | Transmission | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
394 | 394 COOLIDGE | Distribution | Unattended | 69.00 | 12.00 |  | 5.25 | 1 |  |  |  |
395 | 395 COOPER BRIDGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
396 | 396 COOPER TIRE | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
397 | 397 COOPER TOOLS | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
398 | 398 COOPER TOOLS | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
399 | 399 COOSA | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
400 | 400 COOSAWATTEE | Transmission | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  | Capacitor Bank | 1 | 35,000
401 | 401 COOSAWATTEE | Transmission | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
402 | 402 CORINTH ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
403 | 403 CORNELIA | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 63,200
404 | 404 CORNELIA | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
405 | 405 CORNELL AVENUE | Distribution | Unattended | 46.00 | 13.80 |  | 14.00 | 1 |  | Capacitor Bank | 1 | 3,000
406 | 406 CORNELL AVENUE | Distribution | Unattended | 46.00 | 13.80 |  | 14.00 | 1 |  |  |  |
407 | 407 CORPORATE RIDGE | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
408 | 408 COTTON PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 40.00 | 1 |  |  |  |
409 | 409 COTTON PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 33.60 | 1 |  |  |  |
410 | 410 COUNTY FARM ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
411 | 411 COVINGTON INDUSTRIAL | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
412 | 412 CRAWFISH CREEK | Transmission | Unattended | 230.00 | 46.00 |  | 60.00 | 1 |  |  |  |
413 | 413 CRAWFORD | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
414 | 414 CRAWFORDVILLE | Distribution | Unattended | 46.00 | 8.00 |  | 5.25 | 1 |  |  |  |
415 | 415 CREEK PARK | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
416 | 416 CREEKWOOD SUBDIVISION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
417 | 417 CROOKED RIVER | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
418 | 418 CROOKED RIVER | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
419 | 419 CROSSGATE | Transmission | Unattended | 230.00 | 25.00 |  | 50.00 | 1 |  |  |  |
420 | 420 CROSSROADS PARKWAY | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
421 | 421 CRYSTAL BLUE GRANITE PM | Distribution | Unattended | 46.00 | 25.00 |  | 0.84 | 3 |  |  |  |
422 | 422 CRYSTAL LAKE | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
423 | 423 CRYSTAL LAKE | Distribution | Unattended | 25.00 | 12.00 |  | 7.00 | 1 |  |  |  |
424 | 424 CSX INTERMODAL (Fairburn) | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
425 | 425 CSX TRANSPORTATION PM (Fitzgerald) | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
426 | 426 CSX TRANSPORTATION PM (Fitzgerald) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
427 | 427 CULVERTON #3 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
428 | 428 CUMBERLAND | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
429 | 429 CUMMING | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  | Capacitor Bank | 1 | 45,000
430 | 430 CUMMING | Distribution | Unattended | 115.00 | 12.00 |  | 89.60 | 4 |  |  |  |
431 | 431 CURRAHEE HEIGHTS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
432 | 432 CUTHBERT | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
433 | 433 CYPRESS POINT | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
434 | 434 DACULA | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
435 | 435 DAHLONEGA PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
436 | 436 DAHLONEGA PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
437 | 437 DAHLONEGA PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
438 | 438 DALTON | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 90,000
439 | 439 DALTON | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
440 | 440 DAMES FERRY | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
441 | 441 DANIMER | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
442 | 442 DARIEN | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
443 | 443 DAVIDSON MINERAL (Lithonia) | Distribution | Unattended | 46.00 | 2.40 |  | 6.90 | 4 |  |  |  |
444 | 444 DAVIE SLICE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
445 | 445 DAVIE SLICE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
446 | 446 DAVIS STREET | Transmission | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  | Capacitor Bank | 2 | 120,000
447 | 447 DAVIS STREET | Transmission | Unattended | 115.00 | 20.00 |  | 240.00 | 4 |  |  |  |
448 | 448 DAVISBORO PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
449 | 449 DAWSON | Distribution | Unattended | 46.00 | 25.00 |  | 5.25 | 1 |  |  |  |
450 | 450 DAWSON | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
451 | 451 DAWSON FOREST | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  | Capacitor Bank | 1 | 30,000
452 | 452 DAWSON INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
453 | 453 DAWSON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 4 | 46,520
454 | 454 DAWSON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
455 | 455 DEAL BRANCH | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
456 | 456 DEAN FOREST | Transmission | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
457 | 457 DEAN STEEL BUILDINGS | Distribution | Unattended | 46.00 | 0.48 |  | 1.12 | 1 |  |  |  |
458 | 458 DEARING | Distribution | Unattended | 46.00 | 25.00 |  | 7.00 | 1 |  |  |  |
459 | 459 DECATUR | Distribution | Unattended | 115.00 | 20.00 |  | 46.67 | 1 |  |  |  |
460 | 460 DECATUR | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
461 | 461 DECATUR COUNTY INDUSTRIAL | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
462 | 462 DECATUR COUNTY INDUSTRIAL | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
463 | 463 DEKALB COUNTY SCOTT CANDLER WFP | Distribution | Unattended | 115.00 | 4.00 |  | 50.00 | 2 |  |  |  |
464 | 464 DEKALB COUNTY SEWAGE (Snapfinger Rd) | Distribution | Unattended | 25.00 | 12.00 |  | 25.00 | 1 |  |  |  |
465 | 465 DEKALB COUNTY SEWAGE (Snapfinger Rd) | Distribution | Unattended | 20.00 | 12.00 |  | 25.00 | 1 |  |  |  |
466 | 466 DEKALB COUNTY WATER (Holcombe Bridge) | Distribution | Unattended | 25.00 | 4.00 |  | 30.00 | 2 |  |  |  |
467 | 467 DEKALB VOCATIONAL SCHOOL | Distribution | Unattended | 12.00 | 0.48 |  | 1.12 | 1 |  |  |  |
468 | 468 DELTA AIRLINES #1 | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
469 | 469 DELTA AIRLINES #1 | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
470 | 470 DELTA AIRLINES #2 | Distribution | Unattended | 20.00 | 4.00 |  | 2.50 | 1 |  |  |  |
471 | 471 DELTA AIRLINES #2 | Distribution | Unattended | 20.00 | 12.00 |  | 25.00 | 1 |  |  |  |
472 | 472 DEMOREST | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
473 | 473 DEMOREST | Distribution | Unattended | 46.00 | 12.00 | 7 | 10.50 | 1 |  |  |  |
474 | 474 DEPTFORD | Transmission | Unattended | 46.00 | 13.80 |  | 44.80 | 2 |  | Capacitor Bank | 1 | 700
475 | 475 DERING CIRCLE 115 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
476 | 476 DERING CIRCLE 230 | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
477 | 477 DEVEREUX | Distribution | Unattended | 46.00 | 12.00 |  | 1.92 | 2 |  |  |  |
478 | 478 DEVEREUX | Distribution | Unattended | 46.00 | 12.00 |  | 0.83 | 1 |  |  |  |
479 | 479 DEXTER | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
480 | 480 DIAMOND HILL AREA PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
481 | 481 DIAMOND HILL AREA PM | Distribution | Unattended | 46.00 | 12.00 |  |  | 1 |  |  |  |
482 | 482 DILLARD PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
483 | 483 DILLARD PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
484 | 484 DITTLER BROTHERS | Distribution | Unattended | 20.00 | 0.48 |  | 4.20 | 1 |  |  |  |
485 | 485 DIVIDEND ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
486 | 486 DIXIE PECAN PM | Distribution | Unattended | 46.00 | 0.48 |  | 0.05 | 1 |  |  |  |
487 | 487 DIXIE PECAN PM | Distribution | Unattended | 46.00 |  |  | 0.05 | 1 |  |  |  |
488 | 488 DIXIE PIPELINE (Appling) | Distribution | Unattended | 12.00 | 2.40 |  | 7.00 | 2 |  |  |  |
489 | 489 DIXIE PIPELINE (Eatonton) | Distribution | Unattended | 46.00 | 2.40 |  | 3.00 | 3 |  |  |  |
490 | 490 DIXIE PIPELINE (Lumpkin) | Distribution | Unattended | 46.00 | 2.40 |  | 3.45 | 2 |  |  |  |
491 | 491 DIXIE PIPELINE (Milner) | Distribution | Unattended | 69.00 | 2.40 |  | 2.50 | 1 |  |  |  |
492 | 492 DIXIE PIPELINE (Norwood) | Distribution | Unattended | 46.00 | 2.40 |  | 14.00 | 2 |  |  |  |
493 | 493 DIXIE PIPELINE (Putney) | Distribution | Unattended | 12.00 | 4.00 |  | 7.00 | 2 |  |  |  |
494 | 494 DIXIE PIPELINE (Shiloh) | Distribution | Unattended | 115.00 | 2.40 |  | 16.80 | 2 |  |  |  |
495 | 495 DIXIE ROAD | Distribution | Unattended | 69.00 | 12.00 |  | 10.50 | 1 |  |  |  |
496 | 496 DIXON LAKE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
497 | 497 DODD ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
498 | 498 DODGE AGRICULTURAL PARK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
499 | 499 DODGE EASTMAN INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
500 | 500 DOLCO PACKAGING | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
501 | 501 DONALSONVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
502 | 502 DONNA WAY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
503 | 503 DORAVILLE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
504 | 504 DORAVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
505 | 505 DORSEY TRAILERS #2 PM | Distribution | Unattended | 12.00 | 0.48 |  | 0.25 | 3 |  |  |  |
506 | 506 DOSTER ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
507 | 507 DOSTER ROAD #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
508 | 508 DOUBLE BRIDGES ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
509 | 509 DOUBLE CHURCHES ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 33.33 | 1 |  |  |  |
510 | 510 DOUBLEGATE | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 2 |  |  |  |
511 | 511 DRURY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
512 | 512 DRURY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
513 | 513 DSM CHEMICALS | Distribution | Unattended | 115.00 | 4.00 |  | 134.40 | 4 |  |  |  |
514 | 514 DSM CHEMICALS | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
515 | 515 DSM EVERGREEN | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
516 | 516 DUBLIN | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 1 | 30,000
517 | 517 DUBLIN | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
518 | 518 DULUTH | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
519 | 519 DUM JON | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
520 | 520 DUNCAN BRIDGE ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
521 | 521 DUNCAN MILL ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
522 | 522 DUNCAN MILL ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
523 | 523 DURHAM PARK | Distribution | Unattended | 230.00 | 25.00 |  | 67.20 | 2 |  |  |  |
524 | 524 DUTCHTOWN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
525 | 525 EAGLE GRANITE | Distribution | Unattended | 46.00 | 2.40 |  | 0.75 | 3 |  |  |  |
526 | 526 EAST AMERICUS | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
527 | 527 EAST ATHENS | Distribution | Unattended | 115.00 | 12.00 |  | 160.00 | 4 |  |  |  |
528 | 528 EAST AUGUSTA | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
529 | 529 EAST BAINBRIDGE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 76,500
530 | 530 EAST BAINBRIDGE | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
531 | 531 EAST BEACH | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
532 | 532 EAST CUTHBERT | Distribution | Unattended | 46.00 | 12.00 |  | 9.37 | 2 |  |  |  |
533 | 533 EAST DAWSON | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
534 | 534 EAST EVANS | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
535 | 535 EAST EVANS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
536 | 536 EAST EVANS | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
537 | 537 EAST LUMPKIN | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
538 | 538 EAST MACON | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 1 | 30,000
539 | 539 EAST MAYSVILLE | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 60,000
540 | 540 EAST POINT | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  | Capacitor Bank | 1 | 60,000
541 | 541 EAST POINT | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
542 | 542 EAST VALDOSTA | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
543 | 543 EAST VALDOSTA | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
544 | 544 EAST VIDALIA | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
545 | 545 EAST VIDALIA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
546 | 546 EAST VIENNA | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
547 | 547 EASTANOLLEE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
548 | 548 EASTANOLLEE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
549 | 549 EASTMAN | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
550 | 550 EATONTON | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
551 | 551 EATONTON | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
552 | 552 EATONTON PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 33.60 | 1 |  | Capacitor Bank | 1 | 7,800
553 | 553 EATONTON PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 22.40 | 1 |  |  |  |
554 | 554 EATONTON PUMPING PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.28 | 1 |  |  |  |
555 | 555 EATONTON PUMPING PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
556 | 556 EATONTON RADIO STATION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
557 | 557 ECHECONNEE | Distribution | Unattended | 115.00 | 12.00 |  | 37.56 | 1 |  | Capacitor Bank | 2 | 715
558 | 558 EDISON | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
559 | 559 ELANCO | Distribution | Unattended | 115.00 | 4.00 |  | 22.40 | 1 |  |  |  |
560 | 560 ELBERTON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 4,800
561 | 561 ELLAVILLE | Distribution | Unattended | 230.00 | 12.00 |  | 7.50 | 1 |  |  |  |
562 | 562 ELLENWOOD | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
563 | 563 ELLERSLIE | Distribution | Unattended | 230.00 | 25.00 |  | 40.00 | 1 |  |  |  |
564 | 564 ELLIJAY #2 | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
565 | 565 ELLIJAY LUMBER | Distribution | Unattended | 46.00 | 0.48 |  | 0.75 | 3 |  |  |  |
566 | 566 ELLIJAY PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 60.00 | 1 |  |  |  |
567 | 567 ELLIJAY PRIMARY | Transmission | Unattended | 230.00 | 25.00 |  | 40.00 | 1 |  |  |  |
568 | 568 ELLIJAY PRIMARY | Transmission | Unattended | 230.00 | 12.00 |  | 80.00 | 2 |  |  |  |
569 | 569 EMORY | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
570 | 570 EMORY | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
571 | 571 ENCORE RECYCLING | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 1 |  |  |  |
572 | 572 ENGELHARD (Gordon) | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
573 | 573 ENGELHARD (McIntyre) | Distribution | Unattended | 115.00 | 12.00 |  | 112.00 | 2 |  |  |  |
574 | 574 ENGELHARD (Savannah) | Distribution | Unattended | 46.00 | 4.00 |  | 16.80 | 2 |  |  |  |
575 | 575 ENGINEERED FABRICS | Distribution | Unattended | 46.00 | 2.40 |  | 7.50 | 3 |  |  |  |
576 | 576 ENGLISHVILLE | Distribution | Unattended | 46.00 | 25.00 |  | 10.50 | 1 |  |  |  |
577 | 577 ERCO WORLDWIDE | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
578 | 578 ERCO WORLDWIDE | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
579 | 579 ERCO WORLDWIDE | Distribution | Unattended | 230.00 | 25.00 |  | 33.60 | 1 |  |  |  |
580 | 580 ERICK CHURCH ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
581 | 581 ETHICON | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
582 | 582 ETON | Distribution | Unattended | 115.00 | 25.00 |  | 21.00 | 2 |  |  |  |
583 | 583 EUCHEE CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 42.54 | 1 |  |  |  |
584 | 584 EUHARLEE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
585 | 585 EUREKA | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
586 | 586 EVANS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
587 | 587 EVANS CLAY | Distribution | Unattended | 12.00 | 2.40 |  | 2.80 | 3 |  |  |  |
588 | 588 EVANS PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 117,000
589 | 589 EVANS PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
590 | 590 EVERGREEN | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
591 | 591 FACTORY SHOALS ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
592 | 592 FACTORY SHOALS ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
593 | 593 FACTORY SHOALS ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
594 | 594 FAIR ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
595 | 595 FAIR ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
596 | 596 FAIRINGTON RIDGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
597 | 597 FAYETTEVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  |  |  |
598 | 598 FAYETTEVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
599 | 599 FAYETTEVILLE ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  |  |  |
600 | 600 FAYETTEVILLE ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
601 | 601 FAYETTEVILLE ROAD | Distribution | Unattended | 20.00 | 12.00 |  | 22.40 | 1 |  |  |  |
602 | 602 FEDERAL PENITENTIARY | Distribution | Unattended | 20.00 | 4.00 |  | 12.00 | 3 |  |  |  |
603 | 603 FENWICK STREET | Distribution | Unattended | 115.00 | 13.80 |  | 75.00 | 3 |  |  |  |
604 | 604 FERGUSON AVENUE | Transmission | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
605 | 605 FIELDALE (Cornelia) | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
606 | 606 FIELDALE FARMS #1 (Murrayville) | Distribution | Unattended | 25.00 | 0.48 |  | 7.00 | 2 |  |  |  |
607 | 607 FIELDALE FARMS #2 (Murrayville) | Distribution | Unattended | 25.00 | 0.48 |  | 7.00 | 2 |  |  |  |
608 | 608 FIELDALE FARMS (Cornelia) | Distribution | Unattended | 12.00 | 0.48 |  | 7.00 | 2 |  |  |  |
609 | 609 FIELDALE FARMS (Cornelia) | Distribution | Unattended | 12.00 | 0.48 |  | 6.25 | 1 |  |  |  |
610 | 610 FIFE | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
611 | 611 FIFTEENTH STREET | Transmission | Unattended | 115.00 | 13.80 |  | 120.00 | 3 |  | Capacitor Bank | 1 | 60,000
612 | 612 FIFTEENTH STREET | Transmission | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
613 | 613 FIFTY SECOND STREET | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  | Capacitor Bank | 1 | 600,000
614 | 614 FIRST AVENUE | Transmission | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
615 | 615 FIRST UNITED ETHANOL | Distribution | Unattended | 46.00 | 25.00 |  | 21.00 | 2 |  |  |  |
616 | 616 FISHING CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
617 | 617 FITZGERALD | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 63,600
618 | 618 FLAT CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
619 | 619 FLAT CREEK SEWAGE TREATMENT | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
620 | 620 FLAT ROCK ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
621 | 621 FLAT SHOALS ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
622 | 622 FLAV-O-RICH IRVINDALE DAIRY | Distribution | Unattended | 20.00 | 0.48 |  | 3.50 | 1 |  |  |  |
623 | 623 FLEMING | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
624 | 624 FLINT RIVER HYDRO | Generation | Attended | 46.00 | 2.40 |  | 8.00 | 1 |  |  |  |
625 | 625 FLINT RIVER PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 45,000
626 | 626 FLINT RIVER PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
627 | 627 FLIPPEN | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
628 | 628 FLIPPEN | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
629 | 629 FLORIDA ROCK (Griffin) | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
630 | 630 FLOWERY BRANCH | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
631 | 631 FLOWERY BRANCH | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
632 | 632 FOLKSTON | Distribution | Unattended | 115.00 | 25.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 25,000
633 | 633 FOLKSTON | Distribution | Unattended | 25.00 | 20.00 |  | 22.40 | 1 |  |  |  |
634 | 634 FOLKSTON | Distribution | Unattended | 115.00 | 20.00 |  | 25.00 | 1 |  |  |  |
635 | 635 FOREST PARK | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
636 | 636 FOREST PARK | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
637 | 637 FORREST LAKE | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
638 | 638 FORREST LAKE | Distribution | Unattended | 230.00 | 12.00 |  | 50.00 | 2 |  |  |  |
639 | 639 FORREST ROAD (Columbus) | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
640 | 640 FORREST ROAD (Columbus) | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
641 | 641 FORREST ROAD (Macon) | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 63,000
642 | 642 FORREST ROAD (Macon) | Distribution | Unattended | 115.00 | 12.00 |  | 41.70 | 1 |  |  |  |
643 | 643 FORSTMANN (Louisville) | Distribution | Unattended | 115.00 | 12.00 |  | 9.38 | 1 |  |  |  |
644 | 644 FORT BENNING | Transmission | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
645 | 645 FORT BENNING | Transmission | Unattended | 115.00 | 46.00 |  | 56.00 | 1 |  |  |  |
646 | 646 FORT BENNING #2 | Transmission | Unattended | 46.00 | 13.80 |  | 40.00 | 1 |  |  |  |
647 | 647 FORT BENNING #2 | Transmission | Unattended | 115.00 | 46.00 |  | 60.00 | 1 |  |  |  |
648 | 648 FORT GAINES | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
649 | 649 FORT GILLEM | Distribution | Unattended | 115.00 | 12.00 | 14 | 22.40 | 1 |  |  |  |
650 | 650 FORT GILLEM | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
651 | 651 FORT GORDON | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
652 | 652 FORT GORDON #2 | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
653 | 653 FORT GORDON HOSPITAL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
654 | 654 FORT GORDON SOLAR (IC-387) | Generation | Attended | 115.00 | 34.50 |  | 40.00 | 1 |  |  |  |
655 | 655 FORT MCPHERSON | Distribution | Unattended | 20.00 | 12.00 |  | 14.00 | 2 |  |  |  |
656 | 656 FORT STEWART | Distribution | Unattended | 115.00 | 25.00 |  | 100.00 | 2 |  |  |  |
657 | 657 FORT STEWART SOLAR (IC-385) | Generation | Attended | 115.00 | 34.50 |  | 50.00 | 1 |  |  |  |
658 | 658 FORTY FIFTH STREET | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
659 | 659 FORTY FIFTH STREET | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
660 | 660 FOWLER STREET | Distribution | Unattended | 115.00 | 20.00 |  | 112.00 | 2 |  |  |  |
661 | 661 FOWLER STREET | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
662 | 662 FOX TRACE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
663 | 663 FRANKLIN | Distribution | Unattended | 25.00 | 12.00 |  | 5.00 | 2 |  |  |  |
664 | 664 FRANKLIN | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
665 | 665 FRANKLIN ALUMINUM | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
666 | 666 FREDERICA | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
667 | 667 FRITO-LAY (Kathleen) | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
668 | 668 FRUIT OF THE LOOM (Dillard) | Distribution | Unattended | 25.00 | 4.00 |  | 7.00 | 1 |  |  |  |
669 | 669 FULGHUM FIBRES PD (Dewy Rose) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
670 | 670 FURNACE ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
671 | 671 FURYS FERRY | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
672 | 672 FURYS FERRY | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
673 | 673 GA ARMY NATIONAL GUARD | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
674 | 674 GAILLARD PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 80.00 | 2 |  |  |  |
675 | 675 GAINER COTTON GIN | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
676 | 676 GAINESVILLE #1 | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 3 | 129,504
677 | 677 GAINESVILLE #2 | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 3 | 127,800
678 | 678 GAINESVILLE #2 | Distribution | Unattended | 115.00 | 25.00 |  | 55.74 | 2 |  |  |  |
679 | 679 GAINESVILLE #2 | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
680 | 680 GAINESVILLE WATER WORKS | Distribution | Unattended | 46.00 | 4.00 |  | 14.00 | 2 |  |  |  |
681 | 681 GAINESVILLE WATER WORKS #2 | Distribution | Unattended | 46.00 | 2.40 |  | 3.00 | 2 |  |  |  |
682 | 682 GALLAGER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
683 | 683 GARDEN CITY | Distribution | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  |  |  |
684 | 684 GARDEN CITY TERMINAL WEST | Distribution | Unattended | 46.00 | 4.00 |  | 21.00 | 2 |  |  |  |
685 | 685 GARNETT RIDGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
686 | 686 GEO SPECIALTY CHEMICAL (HENKEL) | Distribution | Unattended | 46.00 | 0.60 |  | 3.50 | 1 |  |  |  |
687 | 687 GEORGE ANDREWS LOCK & DAM PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
688 | 688 GEORGETOWN | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
689 | 689 GEORGETOWN (Savannah) | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
690 | 690 GEORGIA BAPTIST VILLAGE | Distribution | Unattended | 12.00 | 4.00 |  | 3.13 | 1 |  |  |  |
691 | 691 GEORGIA BIOMASS | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
692 | 692 GEORGIA BOARD OF CORRECTIONS | Distribution | Unattended | 115.00 | 12.00 |  | 9.38 | 1 |  |  |  |
693 | 693 GEORGIA IRON WORKS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
694 | 694 GEORGIA MARBLE #2 (Whitestone) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
695 | 695 GEORGIA MARBLE #4 (Talking Rock) | Distribution | Unattended | 46.00 | 4.00 |  | 4.69 | 1 |  |  |  |
696 | 696 GEORGIA MARBLE #5 (Marble Hill) | Distribution | Unattended | 46.00 | 2.40 |  | 7.50 | 2 |  |  |  |
697 | 697 GEORGIA MARBLE (Marble Hill) | Distribution | Unattended | 46.00 | 2.40 |  | 9.37 | 2 |  |  |  |
698 | 698 GEORGIA MARBLE (Tate) | Distribution | Unattended | 46.00 | 2.40 |  | 2.50 | 3 |  |  |  |
699 | 699 GEORGIA MARBLE (Tate) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
700 | 700 GEORGIA PACIFIC (Brunswick) | Distribution | Unattended | 115.00 | 13.80 |  | 120.00 | 2 |  |  |  |
701 | 701 GEORGIA PACIFIC (Durand) | Distribution | Unattended | 115.00 | 12.00 |  | 9.38 | 1 |  |  |  |
702 | 702 GEORGIA PACIFIC (Ellabell) | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
703 | 703 GEORGIA PACIFIC (Monticello) | Distribution | Unattended | 69.00 | 12.00 |  | 22.40 | 1 |  |  |  |
704 | 704 GEORGIA PACIFIC (Sterling) | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
705 | 705 GEORGIA PACIFIC (Vienna) | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
706 | 706 GEORGIA PACIFIC (Warrenton) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
707 | 707 GEORGIA PACIFIC GYPSUM (Savannah) | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
708 | 708 GEORGIA PACIFIC SAWMILL (Albany) | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
709 | 709 GEORGIA PORTS AUTHORITY | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
710 | 710 GEORGIA PORTS AUTHORITY | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
711 | 711 GEORGIA SQUARE | Distribution | Unattended | 115.00 | 25.00 |  | 33.30 | 1 |  |  |  |
712 | 712 GEORGIA STATE PATROL - FAA BEACON PM | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
713 | 713 GEORGIA SYNTHETICS | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
714 | 714 GEORGIA TECH | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
715 | 715 GEORGIA TECH RESEARCH (Cobb) | Distribution | Unattended | 46.00 | 4.00 |  | 4.69 | 1 |  |  |  |
716 | 716 GEORGIA TUBING | Distribution | Unattended | 12.00 | 0.48 |  | 5.60 | 2 |  |  |  |
717 | 717 GERDAU | Distribution | Unattended | 230.00 | 34.50 | 14 | 72.80 | 1 | 1 | Capacitor Bank | 5 | 137,400
718 | 718 GERDAU | Distribution | Unattended | 230.00 | 13.80 |  | 60.00 | 1 | 1 |  |  |
719 | 719 GERDAU | Distribution | Unattended | 34.50 |  |  |  | 6 | 1 |  |  |
720 | 720 GERDAU | Distribution | Unattended | 230.00 | 34.50 |  | 72.80 | 1 | 1 |  |  |
721 | 721 GERDAU | Distribution | Unattended | 34.50 | 13.80 |  | 22.40 | 1 | 1 |  |  |
722 | 722 GIBSON | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
723 | 723 GIBSON | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
724 | 724 GILMAN PAPER (Fitzgerald) | Distribution | Unattended | 115.00 | 12.00 |  | 11.20 | 2 |  | Capacitor Bank | 1 | 1,400
725 | 725 GLENNVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
726 | 726 GLYNDALE ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
727 | 727 GOAT ROCK #2 | Distribution | Unattended | 115.00 | 25.00 |  | 14.00 | 2 |  |  |  |
728 | 728 GOAT ROCK HYDRO | Generation | Attended | 12.00 | 0.48 |  | 0.75 | 1 |  |  |  |
729 | 729 GOAT ROCK HYDRO | Generation | Attended | 115.00 | 12.00 |  | 35.00 | 1 |  |  |  |
730 | 730 GOAT ROCK HYDRO | Generation | Attended | 115.00 | 4.00 |  | 12.50 | 1 |  |  |  |
731 | 731 GODFREY ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
732 | 732 GODLEY TRACT | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
733 | 733 GOLD MINE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
734 | 734 GOLDEN PEANUT (Dawson) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
735 | 735 GOODSON ROAD #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
736 | 736 GOODYEAR TIRE (Social Circle) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
737 | 737 GOODYEAR TIRE (Social Circle) | Distribution | Unattended | 46.00 | 2.40 |  | 4.69 | 1 |  |  |  |
738 | 738 GOODYEAR TIRE (Social Circle) | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
739 | 739 GORDON | Transmission | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  | Capacitor Bank | 1 | 45,000
740 | 740 GORDON | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
741 | 741 GORDON ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
742 | 742 GOSHEN (Savannah) | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
743 | 743 GOSHEN (Savannah) | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
744 | 744 GOSSEN | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
745 | 745 GOUGH CITY | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
746 | 746 GRABALL | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
747 | 747 GRADY | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  | Capacitor Bank | 1 | 162,000
748 | 748 GRADY | Distribution | Unattended | 115.00 | 20.00 |  | 80.00 | 2 |  |  |  |
749 | 749 GRADY FLOYD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
750 | 750 GRAHAM PACKAGING #5 PD | Distribution | Unattended | 46.00 | 0.48 |  | 3.75 | 1 |  |  |  |
751 | 751 GRANITEVILLE (Sibley) | Distribution | Unattended | 13.80 | 0.60 |  | 8.40 | 2 |  |  |  |
752 | 752 GRAPHIC PACKAGING | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
753 | 753 GRAPHIC PACKAGING (Augusta) | Distribution | Unattended | 115.00 | 13.80 |  | 67.20 | 2 |  |  |  |
754 | 754 GRAVITT | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
755 | 755 GRAY | Distribution | Unattended | 115.00 | 12.00 |  | 42.00 | 2 |  |  |  |
756 | 756 GREAT SOUTHWEST AMUSEMENT PARK | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
757 | 757 GREAT SOUTHWEST AMUSEMENT PARK | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
758 | 758 GREEN ACRES | Distribution | Unattended | 115.00 | 25.00 |  | 22.40 | 1 |  |  |  |
759 | 759 GREENBRIAR | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
760 | 760 GREENBRIAR | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
761 | 761 GREENS MILL ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
762 | 762 GREENSBORO | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
763 | 763 GREENVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
764 | 764 GREENVILLE PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
765 | 765 GREENWOOD PARK | Distribution | Unattended | 115.00 | 25.00 |  | 120.00 | 2 |  | Capacitor Bank | 2 | 51,800
766 | 766 GRESHAMVILLE PM (RETIRED) | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
767 | 767 GREYSTONE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
768 | 768 GREYSTONE GOLF #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
769 | 769 GRIFFIN ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
770 | 770 GROVE POINT ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
771 | 771 GROVE POINT ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
772 | 772 GROVETOWN PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
773 | 773 GUARDIAN AUTOMOTIVE #1 | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
774 | 774 GULFSTREAM #1 | Distribution | Unattended | 46.00 | 4.00 |  | 9.38 | 1 |  |  |  |
775 | 775 GULFSTREAM #2 | Distribution | Unattended | 46.00 | 4.00 |  | 8.40 | 1 |  |  |  |
776 | 776 GULFSTREAM #3 | Distribution | Unattended | 46.00 | 25.00 |  | 10.00 | 1 |  |  |  |
777 | 777 GULFSTREAM HANGAR | Distribution | Unattended | 46.00 | 4.00 |  | 7.00 | 1 |  |  |  |
778 | 778 GUM CREEK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
779 | 779 GUTHRIE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
780 | 780 GWINNETT COUNTY WFP (Lanier) | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 2 |  |  |  |
781 | 781 GWINNETT COUNTY WFP (Shoal Creek) | Distribution | Unattended | 25.00 | 4.00 |  | 30.00 | 2 |  |  |  |
782 | 782 GWINNETT COUNTY WFP (Shoal Creek) | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 2 |  |  |  |
783 | 783 GWINNETT STREET | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
784 | 784 HAHIRA | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
785 | 785 HAIRSTON ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
786 | 786 HAIRSTON ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
787 | 787 HAMILTON CROSSING ROAD | Distribution | Unattended | 46.00 | 25.00 |  | 7.00 | 1 |  |  |  |
788 | 788 HAMILTON ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  | Capacitor Bank | 2 | 38,400
789 | 789 HANSON AGGREGATES (Athens) | Distribution | Unattended | 46.00 | 2.40 |  | 2.50 | 3 |  |  |  |
790 | 790 HAPEVILLE | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
791 | 791 HARD LABOR CREEK ESTATES PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
792 | 792 HARGROVE ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 112.00 | 2 |  |  |  |
793 | 793 HARLEM | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
794 | 794 HARMONY BLUE GRANITE #1 | Distribution | Unattended | 46.00 | 0.60 |  | 0.75 | 3 |  |  |  |
795 | 795 HARRISON | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
796 | 796 HARTFORD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
797 | 797 HARTSFIELD FIFTH RUNWAY BRIDGE | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
798 | 798 HARTSFIELD JACKSON | Distribution | Unattended | 115.00 | 20.00 |  | 80.00 | 2 |  |  |  |
799 | 799 HARTSFIELD JACKSON | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
800 | 800 HARTWELL | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
801 | 801 HARTWELL SERIES REACTOR | Transmission | Unattended | 230.00 |  |  |  | 6 |  |  |  |
802 | 802 HATCH | Generation | Attended | 4.00 | 0.60 |  | 1.34 | 2 | 1 | Capacitor Bank | 2 | 201,600
803 | 803 HATCH | Generation | Attended | 0.60 | 0.21 |  | 0.17 | 1 | 1 |  |  |
804 | 804 HATCH | Generation | Attended | 25.00 | 4.00 |  | 35.00 | 1 | 1 |  |  |
805 | 805 HATCH | Generation | Attended | 25.00 | 4.00 |  | 33.60 | 1 | 1 |  |  |
806 | 806 HATCH | Generation | Attended | 25.00 | 4.00 |  | 28.00 | 1 | 1 |  |  |
807 | 807 HATCH | Generation | Attended | 230.00 | 4.00 |  | 44.00 | 1 | 1 |  |  |
808 | 808 HATCH | Generation | Attended | 230.00 |  |  | 1200.00 | 1 | 1 |  |  |
809 | 809 HATCH | Generation | Attended | 25.00 | 2.40 |  | 25.00 | 1 | 1 |  |  |
810 | 810 HATCH | Generation | Attended | 500.00 | 25.00 |  | 1200.00 | 3 | 1 |  |  |
811 | 811 HATCH | Generation | Attended | 500.00 |  |  |  | 6 | 1 |  |  |
812 | 812 HATCH SITE #1 | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
813 | 813 HATCH SITE #2 | Distribution | Unattended | 230.00 | 12.00 |  | 25.00 | 1 |  |  |  |
814 | 814 HAWTHORNE | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
815 | 815 HAWTHORNE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
816 | 816 HAZLEHURST PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 1 | 30,000
817 | 817 HAZLEHURST PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
818 | 818 HAZLEHURST WOOD PELLETS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
819 | 819 HEMPHILL WATER TREATMENT | Distribution | Unattended | 115.00 | 4.00 |  | 50.00 | 2 |  |  |  |
820 | 820 HERCULES (Covington) | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
821 | 821 HERCULES (Savannah) | Distribution | Unattended | 13.20 | 0.48 |  | 2.50 | 3 |  |  |  |
822 | 822 HERITAGE HILLS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
823 | 823 HERRINGTON ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
824 | 824 HERTY LABS | Distribution | Unattended | 46.00 | 4.00 |  | 16.00 | 1 |  |  |  |
825 | 825 HIGHTOWER | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
826 | 826 HIGHTOWER ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
827 | 827 HIGHWAY 106 PM (Commerce) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
828 | 828 HIGHWAY 16 PM (Eatonton) | Distribution | Unattended | 46.00 | 12.00 |  | 0.84 | 3 |  |  |  |
829 | 829 HIGHWAY 51 PM (Hartwell) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
830 | 830 HIGHWAY 515 PM (Ellijay) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
831 | 831 HILL STREET | Distribution | Unattended | 230.00 | 20.00 |  | 180.00 | 3 |  |  |  |
832 | 832 HINESVILLE PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 67,200
833 | 833 HINESVILLE PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
834 | 834 HIRAM | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
835 | 835 HIRAM SUDIE PM Retired | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
836 | 836 HOBBS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
837 | 837 HOGANSVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
838 | 838 HOLLY DRIVE INDUSTRIAL | Distribution | Unattended | 115.00 | 13.80 |  | 44.80 | 2 |  |  |  |
839 | 839 HOLLY SPRINGS | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  | Capacitor Bank | 2 | 60,000
840 | 840 HOMERVILLE | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
841 | 841 HON | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
842 | 842 HONDA | Distribution | Unattended | 115.00 | 12.00 |  | 42.00 | 4 |  |  |  |
843 | 843 HORSELEG CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
844 | 844 HOUSTON CHAPEL | Distribution | Unattended | 115.00 | 20.00 |  | 100.00 | 2 |  |  |  |
845 | 845 HOWARD #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
846 | 846 HUB JUNCTION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
847 | 847 HUDSON WIRE | Distribution | Unattended | 46.00 | 0.48 |  | 1.12 | 1 |  |  |  |
848 | 848 HUDSON WIRE | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
849 | 849 HUNTER FIELD | Distribution | Unattended | 46.00 | 13.80 |  | 50.00 | 2 |  |  |  |
850 | 850 HUNTSMAN PIGMENTS | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
851 | 851 HUSQVARNA | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
852 | 852 HUSQVARNA | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
853 | 853 HUTCHINSON ISLAND | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 2 |  |  |  |
854 | 854 IDEAL WOOD PELLETS PD | Distribution | Unattended | 46.00 | 25.00 |  | 5.00 | 1 |  |  |  |
855 | 855 IDLEWOOD | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
856 | 856 INDIAN TRACE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
857 | 857 INDUSTRIAL BOULEVARD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
858 | 858 INDUSTRIAL PARK DRIVE | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
859 | 859 INLAND ROME | Distribution | Unattended | 115.00 | 13.80 |  | 21.00 | 2 |  |  |  |
860 | 860 INLAND ROME | Distribution | Unattended | 115.00 | 13.80 |  | 67.20 | 3 |  |  |  |
861 | 861 INTERFOR (Baxley) | Distribution | Unattended | 46.00 | 4.00 |  | 14.00 | 2 |  |  |  |
862 | 862 INTERNATIONAL PAPER (Gordon) | Distribution | Unattended | 115.00 | 4.00 |  | 15.00 | 2 |  |  |  |
863 | 863 INTERNATIONAL PLAYTEX | Distribution | Unattended | 46.00 | 0.60 |  | 2.00 | 3 |  |  |  |
864 | 864 INTERSTATE CENTRE | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
865 | 865 INTERSTATE CENTRE | Distribution | Unattended | 115.00 | 13.80 |  | 14.00 | 1 |  |  |  |
866 | 866 INTERSTATE PAPER | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
867 | 867 INTERSTATE PAPER | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
868 | 868 INTERSTATE PAPER | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 2 |  |  |  |
869 | 869 INTRENCHMENT CREEK SEWAGE | Distribution | Unattended | 20.00 | 4.00 |  | 4.69 | 1 |  |  |  |
870 | 870 ISSAC HALL PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
871 | 871 J. C. PENNEY | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
872 | 872 J. M. HUBER (Commerce) | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
873 | 873 J. M. HUBER (Reids) | Distribution | Unattended | 46.00 | 4.00 |  | 12.50 | 2 |  |  |  |
874 | 874 J. M. HUBER MINE #1 (Marble Hill) PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
875 | 875 J. R. YOUNG PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
876 | 876 J. T. RYERSON & SON #1 | Distribution | Unattended | 46.00 | 25.00 |  | 10.50 | 2 |  |  |  |
877 | 877 J. T. RYERSON & SON #2 | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
878 | 878 J. WILLFORD PM (Vesta) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
879 | 879 JACK MCDONOUGH | Generation | Attended | 115.00 | 13.20 |  | 98.00 | 1 |  | Capacitor Bank | 1 | 150,000
880 | 880 JACK MCDONOUGH | Generation | Attended | 230.00 | 13.80 |  | 60.00 | 1 |  |  |  |
881 | 881 JACK MCDONOUGH CC #4 | Generation | Attended | 115.00 |  |  | 345.00 | 1 |  |  |  |
882 | 882 JACK MCDONOUGH CC #4 | Generation | Attended | 230.00 |  |  | 345.00 | 1 |  |  |  |
883 | 883 JACK MCDONOUGH CC #4 | Generation | Attended | 230.00 |  |  | 432.00 | 1 |  |  |  |
884 | 884 JACK MCDONOUGH CC #5 | Generation | Attended | 115.00 |  |  | 345.00 | 1 |  |  |  |
885 | 885 JACK MCDONOUGH CC #5 | Generation | Attended | 230.00 |  |  | 432.00 | 1 |  |  |  |
886 | 886 JACK MCDONOUGH CC #5 | Generation | Attended | 230.00 |  |  | 345.00 | 1 |  |  |  |
887 | 887 JACK MCDONOUGH CC #5 | Generation | Attended | 25.00 |  |  | 50.00 | 2 |  |  |  |
888 | 888 JACK MCDONOUGH CC #6 | Generation | Attended | 230.00 |  |  | 432.00 | 1 |  |  |  |
889 | 889 JACK MCDONOUGH CC #6 | Generation | Attended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
890 | 890 JACK MCDONOUGH CC #6 | Generation | Attended | 230.00 |  |  | 690.00 | 2 |  |  |  |
891 | 891 JACKSON COUNTY HEALTH CENTER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
892 | 892 JACKSON COUNTY SENIOR CITIZENS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
893 | 893 JAMES SHORT PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
894 | 894 JAMESTOWN | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
895 | 895 JEFFERSONVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
896 | 896 JEFFERSONVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
897 | 897 JEKYLL ISLAND | Distribution | Unattended | 46.00 | 12.00 |  | 9.37 | 2 |  |  |  |
898 | 898 JEKYLL ISLAND | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
899 | 899 JENNINGS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
900 | 900 JERED BROWN BROTHERS | Distribution | Unattended | 115.00 | 4.00 |  | 11.20 | 2 |  |  |  |
901 | 901 JESSIE PORCH ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
902 | 902 JESUP CITY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
903 | 903 JEWELL | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
904 | 904 JIMMY CARGILL PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
905 | 905 JOHNS CREEK | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
906 | 906 JOHNS CREEK | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
907 | 907 JOHNS CREEK | Distribution | Unattended | 230.00 | 12.00 |  | 40.00 | 1 |  |  |  |
908 | 908 JOHNS CREEK | Distribution | Unattended | 230.00 | 12.00 |  | 67.20 | 2 |  |  |  |
909 | 909 JOHNS MANVILLE INTERNATIONAL | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
910 | 910 JOHNS MANVILLE INTERNATIONAL | Distribution | Unattended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
911 | 911 JOHNSON FERRY ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
912 | 912 JONES CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 41.70 | 1 |  |  |  |
913 | 913 JONESBORO | Distribution | Unattended | 115.00 | 25.00 |  | 56.44 | 1 |  | Capacitor Bank | 1 | 45,000
914 | 914 JUNCTION CITY | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  | Capacitor Bank | 2 | 8,400
915 | 915 JUNCTION CITY | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
916 | 916 JUNCTION CITY MINING PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
917 | 917 JUNCTION CITY MINING #3 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
918 | 918 KAMIN (Wrens) | Distribution | Unattended | 46.00 | 4.00 |  | 5.25 | 1 |  | Capacitor Bank | 2 | 9,600
919 | 919 KAMIN (Wrens) | Distribution | Unattended | 46.00 | 4.00 |  | 7.00 | 1 |  |  |  |
920 | 920 KAMIN (Wrens) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
921 | 921 KAMIN MINE (Thomson) | Distribution | Unattended | 46.00 | 4.00 |  | 10.50 | 2 |  |  |  |
922 | 922 KAOLIN | Transmission | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
923 | 923 KAOLIN | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
924 | 924 KATHWOOD DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
925 | 925 KEDRON | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
926 | 926 KEITH WHITE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
927 | 927 KELLOGGS SNACKS | Distribution | Unattended | 13.80 | 0.48 |  | 3.50 | 1 |  |  |  |
928 | 928 KENNESAW | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
929 | 929 KENNESAW | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
930 | 930 KERRY #2 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
931 | 931 KERRY #3 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
932 | 932 KERRY #4 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
933 | 933 KETTLE CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  | Capacitor Bank | 1 | 31,500
934 | 934 KEYSTONE MEMORIALS | Distribution | Unattended | 46.00 | 0.48 |  | 2.00 | 6 |  |  |  |
935 | 935 KIA MOTORS | Distribution | Unattended | 115.00 | 13.80 |  | 100.00 | 2 |  |  |  |
936 | 936 KIA MOTORS | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
937 | 937 KIMBALL BRIDGE | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
938 | 938 KIMBALL BRIDGE | Distribution | Unattended | 25.00 | 12.00 |  | 33.60 | 1 |  |  |  |
939 | 939 KIMBALL BRIDGE | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
940 | 940 KIMBALL BRIDGE | Distribution | Unattended | 230.00 | 12.00 |  | 40.00 | 1 |  |  |  |
941 | 941 KINCHAFOONEE | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  | Capacitor Bank | 1 | 10,800
942 | 942 KINCHAFOONEE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
943 | 943 KING AMERICA | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
944 | 944 KING SPRINGS ROAD | Distribution | Unattended | 25.00 | 20.00 |  | 25.00 | 1 |  |  |  |
945 | 945 KING SPRINGS ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 120.00 | 2 |  |  |  |
946 | 946 KING STREET | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
947 | 947 KING STREET | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
948 | 948 KINGS BAY SOLAR (IC-391) | Generation | Attended | 230.00 | 34.50 |  | 40.00 | 1 |  |  |  |
949 | 949 KINGSLAND | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 61,500
950 | 950 KINGSTON | Distribution | Unattended | 230.00 | 25.00 |  | 40.00 | 1 |  |  |  |
951 | 951 KIOKEE ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
952 | 952 KIRKHILL MANUFACTURING | Distribution | Unattended | 46.00 | 2.40 |  | 5.00 | 3 |  |  |  |
953 | 953 KIRKWOOD | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
954 | 954 KOYO BEARING | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
955 | 955 KRAFT 115 | Transmission | Attended | 7.62 | 0.12 |  |  | 2 |  |  |  |
956 | 956 L. L. BARNES PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
957 | 957 LAFARGE AGGREGATES #1 Douglasville | Distribution | Unattended | 46.00 | 0.48 |  | 2.24 | 2 |  |  |  |
958 | 958 LAFARGE AGGREGATES #4 PD Oxford | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
959 | 959 LAGRANGE | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 45,000
960 | 960 LAGRANGE | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
961 | 961 LAKE JENNIFER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
962 | 962 LAKE LANIER | Distribution | Unattended | 115.00 | 25.00 |  | 33.33 | 1 |  |  |  |
963 | 963 LAKE LANIER | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
964 | 964 LAKE OCONEE | Distribution | Unattended | 115.00 | 25.00 |  | 33.30 | 1 |  |  |  |
965 | 965 LAKE OCONEE | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
966 | 966 LAKE RIDGE PARKWAY | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 1 |  |  |  |
967 | 967 LAKE SINCLAIR | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
968 | 968 LAKE SUSIE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
969 | 969 LAKE TYRONE PD | Distribution | Unattended | 46.00 | 25.00 |  | 5.00 | 1 |  |  |  |
970 | 970 LAKELAND | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
971 | 971 LAKELAND | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
972 | 972 LAKEWOOD | Distribution | Unattended | 20.00 |  |  |  | 6 |  |  |  |
973 | 973 LAKEWOOD | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
974 | 974 LANGBOARD (Quitman) | Distribution | Unattended | 115.00 | 12.00 |  | 5.00 | 1 |  |  |  |
975 | 975 LANGBOARD (Quitman) | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
976 | 976 LANZATECH | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
977 | 977 LAST LAKE | Distribution | Unattended | 230.00 | 12.00 |  | 33.60 | 1 |  |  |  |
978 | 978 LAWRENCEVILLE HIGHWAY | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  | Capacitor Bank | 1 | 45,000
979 | 979 LEARY | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
980 | 980 LEE HARRIS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
981 | 981 LEESBURG | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
982 | 982 LESLIE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
983 | 983 LEWIS DRIVE | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
984 | 984 LEWIS SIGN PM | Distribution | Unattended | 46.00 | 0.24 |  | 0.03 | 1 |  |  |  |
985 | 985 LEXINGTON COMPONENTS | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
986 | 986 LIBERTY | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
987 | 987 LIKEN INDUSTRIES | Distribution | Unattended | 46.00 | 0.48 |  | 0.50 | 1 |  |  |  |
988 | 988 LILBURN | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  | Capacitor Bank | 1 | 60,000
989 | 989 LIMESTONE CREEK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
990 | 990 LINDALE #2 | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  |  |  |
991 | 991 LINDALE #2 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
992 | 992 LINDBERGH | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
993 | 993 LINWOOD WRF | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
994 | 994 LINWOOD WRF | Distribution | Unattended | 115.00 | 4.00 |  | 6.25 | 1 |  |  |  |
995 | 995 LIQUID CARBONIC | Distribution | Unattended | 13.80 | 4.00 |  | 5.00 | 1 |  |  |  |
996 | 996 LITE-N-TIE (Postell) PM | Distribution | Unattended | 46.00 | 12.00 |  | 1.00 | 3 |  |  |  |
997 | 997 LITHONIA | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
998 | 998 LITHONIA | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
999 | 999 LITHONIA | Distribution | Unattended | 25.00 | 20.00 |  | 33.60 | 1 |  |  |  |
1000 | 1000 LITHONIA LIGHTING | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
1001 | 1001 LITTLE NEW YORK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1002 | 1002 LITTLE RIVER | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1003 | 1003 LITTLE RIVER | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1004 | 1004 LIZELLA | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1005 | 1005 LLOYD SHOALS | Transmission | Attended | 12.00 | 4.00 |  | 5.60 | 1 |  |  |  |
1006 | 1006 LLOYD SHOALS HYDRO | Generation | Attended | 12.00 | 2.40 |  | 12.50 | 1 |  |  |  |
1007 | 1007 LLOYD SHOALS HYDRO | Generation | Attended | 12.00 | 2.40 |  | 10.00 | 1 |  |  |  |
1008 | 1008 LOCH LAUREL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1009 | 1009 LOCKEBY PM | Distribution | Unattended | 46.00 | 7.20 |  | 0.25 | 1 |  |  |  |
1010 | 1010 LOCKHEED MARTIN #1 | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1011 | 1011 LOCKHEED MARTIN #2 | Distribution | Unattended | 46.00 | 12.00 |  | 5.60 | 1 |  |  |  |
1012 | 1012 LOCKHEED MARTIN WIND TUNNEL | Distribution | Unattended | 115.00 | 4.00 |  | 89.60 | 4 |  |  |  |
1013 | 1013 LONG CANE | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1014 | 1014 LOOKOUT VALLEY | Transmission | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1015 | 1015 LOOKOUT VALLEY | Transmission | Unattended | 115.00 | 46.00 |  | 60.00 | 1 |  |  |  |
1016 | 1016 LOUISVILLE AREA #3 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1017 | 1017 LOUISVILLE AREA #7 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1018 | 1018 LOUISVILLE PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1019 | 1019 LUCENT TECHNOLOGIES #1 (OFS FITEL) | Distribution | Unattended | 115.00 | 13.80 |  | 93.33 | 2 |  |  |  |
1020 | 1020 LUCENT TECHNOLOGIES #2 (OFS FITEL) | Distribution | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  |  |  |
1021 | 1021 LUDOWICI PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  | Capacitor Bank | 2 | 67,200
1022 | 1022 LUMBER CITY | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1023 | 1023 LYLE CIRCLE PD | Distribution | Unattended | 46.00 | 25.00 |  | 3.75 | 1 |  |  |  |
1024 | 1024 M A INDUSTRIES | Distribution | Unattended | 12.00 | 0.48 |  | 1.50 | 1 |  |  |  |
1025 | 1025 M&M MARS | Distribution | Unattended | 115.00 | 4.00 |  | 10.50 | 1 |  |  |  |
1026 | 1026 MABLETON | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1027 | 1027 MABLETON | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1028 | 1028 MACON COUNTY PRISON #1 PD (South) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1029 | 1029 MACON COUNTY PRISON #1 PD (South) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1030 | 1030 MADRAS | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1031 | 1031 MADRAS | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1032 | 1032 MAGNOLIA | Transmission | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  | Capacitor Bank | 2 | 90,000
1033 | 1033 MAGNOLIA | Transmission | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1034 | 1034 MAGNOLIA BLUFF | Distribution | Unattended | 25.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1035 | 1035 MAGNOLIA BLUFF | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1036 | 1036 MAGNOLIA MANOR | Distribution | Unattended | 46.00 | 0.48 |  | 1.00 | 2 |  |  |  |
1037 | 1037 MAGNOLIA MANOR | Distribution | Unattended | 46.00 | 0.48 |  | 2.24 | 4 |  |  |  |
1038 | 1038 MAGNOLIA PARK | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1039 | 1039 MAGNOLIA ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1040 | 1040 MAIN STREET PD (RETIRED) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1041 | 1041 MAIN STREET #2 PD | Distribution | Unattended | 46.00 | 25.00 |  | 5.00 | 1 |  |  |  |
1042 | 1042 MALL OF GEORGIA | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
1043 | 1043 MANCHESTER | Distribution | Unattended | 115.00 | 25.00 |  | 42.00 | 4 |  |  |  |
1044 | 1044 MANN ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1045 | 1045 MANSFIELD | Distribution | Unattended | 46.00 | 25.00 |  | 21.00 | 3 |  |  |  |
1046 | 1046 MAR-JAC POULTRY #1 | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1047 | 1047 MARBLE VALLEY | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1048 | 1048 MARION SPENCE ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1049 | 1049 MARK EVANS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1050 | 1050 MARK GLASS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1051 | 1051 MARK GLASS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1052 | 1052 MARSHALLVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1053 | 1053 MARTA ANNEX | Distribution | Unattended | 20.00 | 0.48 |  | 4.69 | 1 |  |  |  |
1054 | 1054 MARTIN HEIGHTS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1055 | 1055 MARTIN MARIETTA (Camak) | Distribution | Unattended | 46.00 | 2.40 |  | 4.50 | 3 |  |  |  |
1056 | 1056 MARTIN MARIETTA (Gray) | Distribution | Unattended | 46.00 | 2.40 |  | 6.25 | 1 |  |  |  |
1057 | 1057 MARTIN MARIETTA (Johns Creek) | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1058 | 1058 MARTIN MARIETTA (Junction City) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1059 | 1059 MARTIN MARIETTA (Martinez) | Distribution | Unattended | 13.80 | 2.40 |  | 5.00 | 1 |  |  |  |
1060 | 1060 MARTIN MARIETTA (Tyrone) | Distribution | Unattended | 46.00 | 2.40 |  | 4.17 | 5 |  |  |  |
1061 | 1061 MARTIN MARIETTA (Warrenton) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 3 |  |  |  |
1062 | 1062 MARVIN GRIFFIN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1063 | 1063 MARVIN GRIFFIN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 33.00 | 1 |  |  |  |
1064 | 1064 MCBEAN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1065 | 1065 MCBEAN ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1066 | 1066 MCCREE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1067 | 1067 MCCREE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.56 | 2 |  |  |  |
1068 | 1068 MCDONOUGH | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 63,000
1069 | 1069 MCDONOUGH | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1070 | 1070 MCDONOUGH | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1071 | 1071 MCDONOUGH CONSTRUCTION | Distribution | Unattended | 20.00 | 0.28 |  | 0.34 | 3 |  |  |  |
1072 | 1072 MCGRAU FORD | Transmission | Unattended | 13.80 | 0.48 |  | 1.00 | 1 |  |  |  |
1073 | 1073 MCINTOSH | Transmission | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1074 | 1074 MCINTOSH | Transmission | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1075 | 1075 MCINTOSH CC | Generation | Attended | 230.00 |  |  | 645.00 | 3 |  |  |  |
1076 | 1076 MCINTOSH CC | Generation | Attended | 230.00 |  |  | 250.00 | 1 |  |  |  |
1077 | 1077 MCINTOSH CC | Generation | Attended | 230.00 |  |  | 670.00 | 2 |  |  |  |
1078 | 1078 MCINTOSH CT | Generation | Attended | 13.80 | 0.48 | 0 | 4.50 | 3 |  |  |  |
1079 | 1079 MCINTOSH CT | Generation | Attended | 13.80 | 0.48 | 0 | 2.00 | 1 |  |  |  |
1080 | 1080 MCINTOSH CT | Generation | Attended | 13.80 | 13.80 |  | 5.98 | 1 |  |  |  |
1081 | 1081 MCINTOSH CT | Generation | Attended | 13.80 | 0.48 | 0 | 17.94 | 3 |  |  |  |
1082 | 1082 MCINTOSH CT | Generation | Attended | 230.00 | 13.80 |  | 880.00 | 4 |  |  |  |
1083 | 1083 MCINTOSH TRAIL | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1084 | 1084 MCMANUS | Generation | Attended | 13.80 | 2.40 |  | 4.48 | 2 |  | Capacitor Bank | 1 | 30,000
1085 | 1085 MCMANUS | Generation | Attended | 230.00 | 13.20 |  | 396.00 | 3 |  |  |  |
1086 | 1086 MCMANUS | Generation | Attended | 13.80 | 2.40 |  | 3.22 | 1 |  |  |  |
1087 | 1087 MCMANUS | Generation | Attended | 115.00 | 13.20 |  | 56.00 | 1 |  |  |  |
1088 | 1088 MCMANUS | Generation | Attended | 2.40 | 0.48 |  | 0.56 | 1 |  |  |  |
1089 | 1089 MCMANUS | Generation | Attended | 2.40 | 0.48 |  | 0.30 | 1 |  |  |  |
1090 | 1090 MCMANUS | Generation | Attended | 13.80 | 0.48 |  | 3.86 | 3 |  |  |  |
1091 | 1091 MCMANUS | Generation | Attended | 13.80 | 2.40 |  | 3.36 | 2 |  |  |  |
1092 | 1092 MCMANUS | Generation | Attended | 13.80 | 2.40 |  | 2.50 | 1 |  |  |  |
1093 | 1093 MCMANUS | Generation | Attended | 115.00 | 13.20 |  | 120.00 | 2 |  |  |  |
1094 | 1094 MCMANUS | Generation | Attended | 2.40 | 0.48 |  | 2.24 | 1 |  |  |  |
1095 | 1095 MCPHERSON MANUFACTURING | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1096 | 1096 MCRAE | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 30,000
1097 | 1097 MEADOWS LAKE #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
1098 | 1098 MEADOWS SUBDIVISION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1099 | 1099 MEDUSA PORTLAND CEMENT | Distribution | Unattended | 115.00 | 4.00 |  | 37.50 | 4 |  |  |  |
1100 | 1100 MEDUSA PORTLAND CEMENT | Distribution | Unattended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
1101 | 1101 MEDUSA PORTLAND CEMENT #2 | Distribution | Unattended | 46.00 | 4.00 |  | 1.67 | 5 |  |  |  |
1102 | 1102 MEDUSA PORTLAND CEMENT #3 | Distribution | Unattended | 46.00 | 2.40 |  | 1.50 | 3 |  |  |  |
1103 | 1103 MEIGS | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1104 | 1104 MELDRIM | Transmission | Unattended | 115.00 | 46.00 | 13 | 112.00 | 1 |  | Capacitor Bank | 1 | 30,000
1105 | 1105 MELDRIM | Transmission | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1106 | 1106 MELDRIM | Transmission | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1107 | 1107 MENLO | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1108 | 1108 MERIWETHER PARK | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1109 | 1109 MERIWETHER ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1110 | 1110 METAL PRODUCTS #1 | Distribution | Unattended | 12.00 | 0.48 |  | 1.12 | 1 |  |  |  |
1111 | 1111 METTER | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 2,400
1112 | 1112 METTER AREA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1113 | 1113 METTER PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 37,500
1114 | 1114 METTER PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1115 | 1115 MIDVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 6 | 1 |  |  |
1116 | 1116 MILL CITY SEWAGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1117 | 1117 MILL CITY SEWAGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1118 | 1118 MILLEDGEVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 30,000
1119 | 1119 MILLEDGEVILLE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1120 | 1120 MILLEN | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1121 | 1121 MILLEN AREA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1122 | 1122 MILLEN AREA #3 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1123 | 1123 MILLEN PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1124 | 1124 MILLHAVEN ANNEX | Transmission | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1125 | 1125 MILLHAVEN ANNEX | Transmission | Unattended | 115.00 | 46.00 |  | 112.00 | 1 |  |  |  |
1126 | 1126 MILLIKEN (Alma) | Distribution | Unattended | 115.00 | 4.00 |  | 37.50 | 4 |  |  |  |
1127 | 1127 MILLIKEN (Duncan Stewart) Lagrange | Distribution | Unattended | 46.00 | 0.60 |  | 3.50 | 1 |  |  |  |
1128 | 1128 MILLIKEN (Kingsley Mill) Thomson | Distribution | Unattended | 115.00 | 4.00 |  | 22.40 | 1 |  |  |  |
1129 | 1129 MILLIKEN (Lagrange) | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1130 | 1130 MILLIKEN (Lagrange) | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1131 | 1131 MILLIKEN (New Holland) Gainesville | Distribution | Unattended | 46.00 | 0.60 |  | 7.00 | 1 |  |  |  |
1132 | 1132 MILLIKEN (New Holland) Gainesville | Distribution | Unattended | 46.00 | 0.60 |  | 14.00 | 2 |  |  |  |
1133 | 1133 MILLIKEN (Pine Mountain) | Distribution | Unattended | 25.00 | 0.60 |  | 3.50 | 1 |  |  |  |
1134 | 1134 MILLIKEN (Pine Mountain) | Distribution | Unattended | 25.00 | 0.60 |  | 4.20 | 1 |  |  |  |
1135 | 1135 MILLIRONS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1136 | 1136 MILLIRONS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1137 | 1137 MINOLA DRIVE | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
1138 | 1138 MISSION POND | Distribution | Attended | 115.00 | 34.50 |  | 55.00 | 1 |  |  |  |
1139 | 1139 MITCHELL 115 | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 103,500
1140 | 1140 MITCHELL 115 | Transmission | Unattended | 115.00 | 12.00 |  | 10.00 | 1 |  |  |  |
1141 | 1141 MODULAR CONTAINER SYSTEMS | Distribution | Unattended | 46.00 | 0.48 |  | 1.12 | 1 |  |  |  |
1142 | 1142 MOHAWK INDUSTRIES (East Dublin) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1143 | 1143 MOHAWK INDUSTRIES (Lyerly) | Distribution | Unattended | 46.00 | 4.00 |  | 7.00 | 1 |  |  |  |
1144 | 1144 MOHAWK INDUSTRIES (Summerville) | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
1145 | 1145 MOLENA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1146 | 1146 MOLENA PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 30,000
1147 | 1147 MONK ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 31.50 | 3 |  |  |  |
1148 | 1148 MONROE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1149 | 1149 MONROE | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
1150 | 1150 MONROE INDUSTRIAL PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1151 | 1151 MONTEZUMA | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  | Capacitor Bank | 2 | 33,000
1152 | 1152 MONTEZUMA | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1153 | 1153 MONTGOMERYVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1154 | 1154 MORELAND AVENUE | Distribution | Unattended | 115.00 | 20.00 |  | 120.00 | 2 |  |  |  |
1155 | 1155 MORELAND WAY | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1156 | 1156 MORGAN FALLS | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1157 | 1157 MORGAN FALLS | Distribution | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  |  |  |
1158 | 1158 MORGAN FALLS HYDRO | Generation | Attended | 20.00 | 4.00 |  | 15.00 | 2 |  |  |  |
1159 | 1159 MORGAN PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1160 | 1160 MORGANVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
1161 | 1161 MORGANVILLE | Distribution | Unattended | 161.00 | 46.00 |  | 22.40 | 1 |  |  |  |
1162 | 1162 MORNINGSIDE | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1163 | 1163 MOSSY BRANCH BATTERY STORAGE | Generation | Attended | 115.00 | 34.50 |  | 75.00 | 1 |  |  |  |
1164 | 1164 MOULTRIE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 3 | 69,300
1165 | 1165 MOULTRIE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1166 | 1166 MOULTRIE | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1167 | 1167 MOULTRIE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1168 | 1168 MOUNT VERNON | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1169 | 1169 MOUNT VERNON MILLS (Alto) | Distribution | Unattended | 115.00 | 12.00 |  | 31.50 | 3 |  |  |  |
1170 | 1170 MOUNT VERNON MILLS (Cleveland) | Distribution | Unattended | 25.00 | 0.60 |  | 5.60 | 2 |  |  |  |
1171 | 1171 MOUNT VERNON MILLS (Trion) | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1172 | 1172 MOUNT ZION | Distribution | Unattended | 46.00 | 12.00 |  | 1.50 | 3 |  |  |  |
1173 | 1173 MOUNTAIN HILL | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1174 | 1174 MOUNTAIN SPRINGS #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
1175 | 1175 MOUNTAIN VIEW | Distribution | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  | Capacitor Bank | 1 | 45,000
1176 | 1176 MOUNTAIN VIEW | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1177 | 1177 MOUNTAIN VIEW | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
1178 | 1178 MRS. SMITHS BAKERIES | Distribution | Unattended | 20.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1179 | 1179 MRS. SMITHS BAKERIES | Distribution | Unattended | 20.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1180 | 1180 MUD CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1181 | 1181 MULKEY ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 22.40 | 1 |  |  |  |
1182 | 1182 MULLITE #2 | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1183 | 1183 MULLITE #2 | Distribution | Unattended | 115.00 | 4.00 |  | 21.00 | 2 |  |  |  |
1184 | 1184 MYSTERY VALLEY | Distribution | Unattended | 115.00 | 25.00 |  | 120.00 | 2 |  |  |  |
1185 | 1185 NACOOCHEE | Generation | Attended | 46.00 |  |  | 7.00 | 1 |  |  |  |
1186 | 1186 NACOOCHEE | Generation | Attended | 46.00 | 7.20 |  | 1.67 | 2 |  |  |  |
1187 | 1187 NASHVILLE #1 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1188 | 1188 NASHVILLE #1 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1189 | 1189 NASHVILLE MILLS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1190 | 1190 NATIONAL BEEF | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
1191 | 1191 NATIONAL BEEF | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
1192 | 1192 NECO | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1193 | 1193 NECO | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
1194 | 1194 NEW RIVERSIDE OCHRE | Distribution | Unattended | 46.00 | 2.40 |  | 1.50 | 3 |  |  |  |
1195 | 1195 NEWELL RECYCLING #1 (East Point) | Distribution | Unattended | 20.00 | 4.00 |  | 5.00 | 1 |  |  |  |
1196 | 1196 NEWELL RECYCLING (Norcross) | Transmission | Unattended | 115.00 | 4.00 |  | 7.00 | 1 |  |  |  |
1197 | 1197 NEWTON | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  |  |  |
1198 | 1198 NIPPER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1199 | 1199 NORDIC COLD STORAGE #2 (Doraville) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1200 | 1200 NORDIC COLD STORAGE (Doraville) | Distribution | Unattended | 46.00 | 0.48 |  | 3.22 | 3 |  |  |  |
1201 | 1201 NORDIC COLD STORAGE (Hapeville) | Distribution | Unattended | 20.00 | 0.48 |  | 2.00 | 1 |  |  |  |
1202 | 1202 NORMAN PARK ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1203 | 1203 NORTH ATHENS | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1204 | 1204 NORTH AWRF | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1205 | 1205 NORTH CLARKESVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1206 | 1206 NORTH COLUMBUS | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 30,000
1207 | 1207 NORTH CONYERS | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1208 | 1208 NORTH DRUID HILLS | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1209 | 1209 NORTH DRUID HILLS | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1210 | 1210 NORTH DRUID HILLS | Distribution | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  |  |  |
1211 | 1211 NORTH FAIRMOUNT | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1212 | 1212 NORTH FORK | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1213 | 1213 NORTH GRIFFIN | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1214 | 1214 NORTH HIGHLANDS | Generation | Attended | 12.00 | 4.00 |  | 23.00 | 1 |  |  |  |
1215 | 1215 NORTH HIGHLANDS | Generation | Attended | 12.00 | 4.00 |  | 14.00 | 1 |  |  |  |
1216 | 1216 NORTH JEFFERSON | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1217 | 1217 NORTH JEFFERSON | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1218 | 1218 NORTH JEFFERSON | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1219 | 1219 NORTH KEITHSBURG | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
1220 | 1220 NORTH KITE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1221 | 1221 NORTH MACON | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1222 | 1222 NORTH MARTIN | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1223 | 1223 NORTH MCRAE | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1224 | 1224 NORTH METTER | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1225 | 1225 NORTH MILLEDGEVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1226 | 1226 NORTH MONTICELLO | Transmission | Unattended | 230.00 | 69.00 | 13 | 60.00 | 1 |  |  |  |
1227 | 1227 NORTH OCONEE WRF | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1228 | 1228 NORTH RIVERSIDE | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1229 | 1229 NORTH ROCKMART | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1230 | 1230 NORTH SHALLOWFORD ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1231 | 1231 NORTH SPRINGS | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1232 | 1232 NORTH STATESBORO | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1233 | 1233 NORTH STATESBORO | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1234 | 1234 NORTH THOMASTON | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1235 | 1235 NORTH THOMSON | Distribution | Unattended | 46.00 | 25.00 |  | 14.00 | 2 |  |  |  |
1236 | 1236 NORTH THOMSON | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1237 | 1237 NORTH TIFTON | Transmission | Unattended | 500.00 |  |  |  | 3 |  | Capacitor Bank | 2 | 153,000
1238 | 1238 NORTH TIFTON | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1239 | 1239 NORTH VALDOSTA | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1240 | 1240 NORTH VALDOSTA | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1241 | 1241 NORTHCREST | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1242 | 1242 NORTHEAST WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1243 | 1243 NORTHPARK | Distribution | Unattended | 230.00 | 20.00 |  | 112.00 | 2 |  | Capacitor Bank | 1 | 120,900
1244 | 1244 NORTHPARK | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1245 | 1245 NORTHSIDE DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  | Capacitor Bank | 1 | 60,800
1246 | 1246 NORTHSIDE DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1247 | 1247 NORTHWEST 115 | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1248 | 1248 NORTHWEST 115 | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1249 | 1249 NORTHWEST PERRY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1250 | 1250 NORTHWEST WAYCROSS | Distribution | Unattended | 25.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1251 | 1251 NORTHWEST WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1252 | 1252 NORTHWEST WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1253 | 1253 NORTHWINDS | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1254 | 1254 NOWHERE ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  |  | 1 |  |  |  |
1255 | 1255 NUTRASWEET | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1256 | 1256 NUTRASWEET | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1257 | 1257 NUTRASWEET | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
1258 | 1258 OAK GROVE | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1259 | 1259 OAK GROVE | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
1260 | 1260 OAK STREET | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1261 | 1261 OAK STREET | Distribution | Unattended | 115.00 | 12.00 |  | 33.00 | 1 |  |  |  |
1262 | 1262 OAKEY WOODS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1263 | 1263 OAKFIELD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1264 | 1264 OCHLOCKNEE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1265 | 1265 OCHLOCKNEE PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 7,800
1266 | 1266 OCMULGEE STREET | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1267 | 1267 OCMULGEE STREET | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1268 | 1268 OCONEE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1269 | 1269 OGLETHORPE MALL | Distribution | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  |  |  |
1270 | 1270 OHOOPEE RIVER | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1271 | 1271 OLD ALABAMA ROAD | Distribution | Unattended | 230.00 | 12.00 |  | 67.20 | 2 |  | Capacitor Bank | 1 | 64,800
1272 | 1272 OLD ALABAMA ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1273 | 1273 OLD ALABAMA ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1274 | 1274 OLD DALTON ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1275 | 1275 OLD HICKORY | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1276 | 1276 OLD MAUK ROAD | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 1 |  | Capacitor Bank | 2 | 9,600
1277 | 1277 OLD NATIONAL | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1278 | 1278 OLD RIVER ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1279 | 1279 OLD SAVANAH ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1280 | 1280 OLIN | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
1281 | 1281 OLIVER DAM HYDRO | Generation | Attended | 115.00 | 7.20 |  | 45.00 | 2 |  |  |  |
1282 | 1282 OLIVER DAM HYDRO | Generation | Attended | 115.00 | 7.20 |  | 30.00 | 1 |  |  |  |
1283 | 1283 OLIVER ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1284 | 1284 OPHELIA SMITH PM | Distribution | Unattended |  |  |  |  | 1 |  |  |  |
1285 | 1285 ORANGE | Distribution | Unattended | 115.00 | 25.00 |  | 35.87 | 1 |  |  |  |
1286 | 1286 ORANGE | Distribution | Unattended | 115.00 | 25.00 |  | 45.06 | 1 |  |  |  |
1287 | 1287 ORANGE HILL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1288 | 1288 ORCHARD HILL | Distribution | Unattended | 69.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1289 | 1289 OVERLAND TRAIL LAND PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1290 | 1290 OWENS BROCKWAY (Sylvan Road) | Distribution | Unattended | 20.00 | 4.00 |  | 25.00 | 4 |  |  |  |
1291 | 1291 OWENS CORNING FIBERGLASS | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1292 | 1292 OWENS ILLINOIS (Hamilton Boulevard) | Distribution | Unattended | 20.00 | 0.48 |  | 2.58 | 2 |  |  |  |
1293 | 1293 OWL HEAD #2 | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1294 | 1294 OXFORD ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 53.20 | 1 |  | Capacitor Bank | 2 | 12,600
1295 | 1295 PACES FERRY | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1296 | 1296 PACKAGING CORPORATION (Clyattville) | Distribution | Unattended | 69.00 | 4.00 |  | 50.00 | 2 |  |  |  |
1297 | 1297 PACKAGING CORPORATION (Macon) | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1298 | 1298 PACKAGING CORPORATION (Macon) | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1299 | 1299 PACTIV #2 | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1300 | 1300 PACTIV #2 | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1301 | 1301 PACTIV #3 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1302 | 1302 PACTIV #4 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1303 | 1303 PACTIV #6 | Distribution | Unattended | 46.00 | 0.48 |  | 10.50 | 3 |  |  |  |
1304 | 1304 PACTIV #7 | Distribution | Unattended | 46.00 | 0.48 |  | 5.60 | 2 |  |  |  |
1305 | 1305 PALM STREET | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1306 | 1306 PALM STREET | Distribution | Unattended | 115.00 | 25.00 |  | 45.80 | 2 |  |  |  |
1307 | 1307 PALMER CREEK | Distribution | Unattended | 230.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1308 | 1308 PALMYRA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 58,500
1309 | 1309 PALMYRA | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1310 | 1310 PARK | Distribution | Unattended | 20.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1311 | 1311 PARK | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1312 | 1312 PARKDALE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1313 | 1313 PARKENSON CHURCH ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1314 | 1314 PARKENSON CHURCH ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1315 | 1315 PARKWAY | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 2 |  |  |  |
1316 | 1316 PASCOE STEEL | Distribution | Unattended | 12.00 | 0.48 |  | 1.50 | 1 |  |  |  |
1317 | 1317 PATRIOTS PARK | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1318 | 1318 PATTON SEED PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1319 | 1319 PAUL WINNIE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.28 | 1 |  |  |  |
1320 | 1320 PAUL WINNIE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1321 | 1321 PCS NITROGEN | Distribution | Unattended | 115.00 | 13.80 |  | 100.00 | 2 |  |  |  |
1322 | 1322 PEACH ORCHARD | Distribution | Unattended | 13.80 | 12.00 |  | 25.00 | 1 |  |  |  |
1323 | 1323 PEACH ORCHARD | Distribution | Unattended | 230.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1324 | 1324 PEACH ORCHARD | Distribution | Unattended | 230.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1325 | 1325 PEACHTREE | Distribution | Unattended | 230.00 | 20.00 |  | 180.00 | 3 |  |  |  |
1326 | 1326 PEACHTREE | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1327 | 1327 PEACHTREE CITY #2 | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  | Capacitor Bank | 2 | 38,400
1328 | 1328 PEACHTREE CORNERS | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1329 | 1329 PEACHTREE CORNERS | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1330 | 1330 PEARSON | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1331 | 1331 PEEPLES VALLEY | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1332 | 1332 PEEPLES VALLEY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1333 | 1333 PELHAM | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
1334 | 1334 PEMBROKE | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1335 | 1335 PENN CAMP ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1336 | 1336 PERIMETER CENTER | Distribution | Unattended | 230.00 | 20.00 |  | 168.00 | 3 |  |  |  |
1337 | 1337 PERRY | Transmission | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  | Capacitor Bank | 1 | 45,000
1338 | 1338 PERRY | Transmission | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1339 | 1339 PERRY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1340 | 1340 PETERSBURG ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1341 | 1341 PETERSON CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1342 | 1342 PETTIT CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 33.30 | 1 |  | Capacitor Bank | 1 | 33,000
1343 | 1343 PETTIT CREEK | Distribution | Unattended | 115.00 | 46.00 |  | 56.00 | 1 |  |  |  |
1344 | 1344 PHARMATECH | Distribution | Unattended | 46.00 | 0.48 |  | 4.69 | 1 |  |  |  |
1345 | 1345 PHARMATECH | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1346 | 1346 PHILEMA ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1347 | 1347 PILGRIMS PRIDE #1 (Athens) | Distribution | Unattended | 46.00 | 0.48 |  | 1.93 | 1 |  |  |  |
1348 | 1348 PILGRIMS PRIDE #1 (Athens) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1349 | 1349 PILGRIMS PRIDE #2 (Athens) | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 1 |  |  |  |
1350 | 1350 PILGRIMS PRIDE #3 (Athens) | Distribution | Unattended | 12.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1351 | 1351 PILGRIMS PRIDE (Canton) | Distribution | Unattended | 25.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1352 | 1352 PILGRIMS PRIDE (Industrial Boulevard) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1353 | 1353 PINE GROVE PRIMARY | Transmission | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  | Capacitor Bank | 1 | 117,000
1354 | 1354 PINE MOUNTAIN | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
1355 | 1355 PINSON | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  | Capacitor Bank | 1 | 49,500
1356 | 1356 PINSON | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1357 | 1357 PITTMAN ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 33,600
1358 | 1358 PITTS CHAPEL ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1359 | 1359 PLAINS | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1360 | 1360 PLANTATION PIPELINE PM (Bio) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1361 | 1361 PLANTATION PIPELINE (Austell) | Distribution | Unattended | 115.00 | 4.00 |  | 11.20 | 2 |  |  |  |
1362 | 1362 PLANTATION PIPELINE (Bremen) | Distribution | Unattended | 115.00 | 4.00 |  | 44.80 | 2 |  |  |  |
1363 | 1363 PLANTATION PIPELINE (Doraville) | Distribution | Unattended | 46.00 | 4.00 |  | 6.25 | 1 |  |  |  |
1364 | 1364 PLANTATION PIPELINE (Lafayette) | Distribution | Unattended | 20.00 | 2.40 |  | 3.00 | 6 |  |  |  |
1365 | 1365 PLANTATION PIPELINE (Neese) | Distribution | Unattended | 115.00 | 4.00 |  | 21.00 | 2 |  |  |  |
1366 | 1366 PLANTATION PIPELINE (Subligna) | Distribution | Unattended | 46.00 | 2.40 |  | 2.50 | 3 |  |  |  |
1367 | 1367 PLANTATION ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  | Capacitor Bank | 1 | 58,500
1368 | 1368 PLEASANTDALE ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 120.00 | 2 |  |  |  |
1369 | 1369 POMONA | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1370 | 1370 POMONA | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1371 | 1371 PONCE DE LEON | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  | Capacitor Bank | 2 | 120,000
1372 | 1372 PONCE DE LEON | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1373 | 1373 POOLER | Distribution | Unattended | 46.00 | 13.80 |  | 10.50 | 1 |  |  |  |
1374 | 1374 POOLER | Distribution | Unattended | 46.00 | 13.80 |  | 28.00 | 2 |  |  |  |
1375 | 1375 PORTER PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
1376 | 1376 PORTERDALE PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  | Capacitor Bank | 3 | 182,340
1377 | 1377 PORTERDALE PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1378 | 1378 PORTERDALE PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1379 | 1379 PORTERDALE PRIMARY | Distribution | Unattended | 46.00 | 12.00 | 7 | 10.50 | 1 |  |  |  |
1380 | 1380 PORTLAND | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1381 | 1381 POTTERVILLE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1382 | 1382 POTTERY OUTLET PD (RETIRED) | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1383 | 1383 POULAN | Distribution | Unattended | 46.00 | 12.00 |  | 1.67 | 2 |  |  |  |
1384 | 1384 POULAN | Distribution | Unattended | 46.00 | 12.00 |  | 1.25 | 1 |  |  |  |
1385 | 1385 POWDER SPRINGS | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1386 | 1386 POWDER SPRINGS | Distribution | Unattended | 115.00 | 25.00 |  | 33.60 | 1 |  |  |  |
1387 | 1387 POWER LINE ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 10.50 | 1 |  |  |  |
1388 | 1388 POWER PARTNERS | Distribution | Unattended | 46.00 | 4.00 |  | 5.25 | 1 |  |  |  |
1389 | 1389 POWER PARTNERS | Distribution | Unattended | 46.00 | 4.00 |  | 3.75 | 1 |  |  |  |
1390 | 1390 POWERS FERRY | Distribution | Unattended | 230.00 | 20.00 |  | 240.00 | 4 |  |  |  |
1391 | 1391 PPG INDUSTRIES | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1392 | 1392 PRATT & WHITNEY | Distribution | Unattended | 115.00 | 13.80 |  | 44.80 | 2 |  |  |  |
1393 | 1393 PRAYON | Distribution | Unattended | 13.80 | 4.00 |  | 2.80 | 1 |  |  |  |
1394 | 1394 PREFERRED COMPOUNDING #1 PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1395 | 1395 PREFERRED COMPOUNDING #2 PM | Distribution | Unattended | 46.00 | 4.00 |  | 0.25 | 1 |  |  |  |
1396 | 1396 PREFERRED COMPOUNDING #2 PM | Distribution | Unattended | 46.00 | 4.00 |  | 0.56 | 2 |  |  |  |
1397 | 1397 PREFERRED COMPOUNDING #4 PD | Distribution | Unattended | 46.00 | 4.00 |  | 2.50 | 1 |  |  |  |
1398 | 1398 PRESIDENT STREET SEWAGE | Distribution | Unattended | 46.00 | 4.00 |  | 21.00 | 2 |  |  |  |
1399 | 1399 PRESTON | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  |  |  |
1400 | 1400 PRINGLE ROAD | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1401 | 1401 PROCTER & GAMBLE (Albany) | Distribution | Unattended | 115.00 | 13.80 |  | 93.33 | 2 |  |  |  |
1402 | 1402 PROCTER & GAMBLE (Albany) | Distribution | Unattended | 115.00 | 13.80 |  | 60.00 | 1 |  |  |  |
1403 | 1403 PROFILE EXTRUSIONS PD | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1404 | 1404 PROPEX #1 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1405 | 1405 PROPEX #1 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1406 | 1406 PROPEX #10 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1407 | 1407 PROPEX #11 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1408 | 1408 PROPEX #2 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 5.04 | 3 |  |  |  |
1409 | 1409 PROPEX #3 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 5.60 | 2 |  |  |  |
1410 | 1410 PROPEX #4 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1411 | 1411 PROPEX #4 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1412 | 1412 PROPEX #4 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1413 | 1413 PROPEX #5 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1414 | 1414 PROPEX #5 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1415 | 1415 PROPEX #6 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
1416 | 1416 PROPEX #7 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 4.20 | 1 |  |  |  |
1417 | 1417 PROPEX #7 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1418 | 1418 PROPEX #9 (Hazlehurst) | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1419 | 1419 PUBLIC SAFETY TRAINING CENTER | Distribution | Unattended | 115.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1420 | 1420 PULASKI | Distribution | Unattended | 46.00 | 12.00 |  | 3.75 | 3 | 1 |  |  |
1421 | 1421 PULASKI SEWAGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1422 | 1422 PURCELL ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1423 | 1423 PUTNAM PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1424 | 1424 PYRAMAX CERAMICS | Distribution | Unattended | 46.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1425 | 1425 QUACCO ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1426 | 1426 QUACCO ROAD | Distribution | Unattended | 115.00 | 13.80 |  | 33.30 | 1 |  |  |  |
1427 | 1427 QUAIL HOLLOW PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1428 | 1428 QUAIL RIDGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1429 | 1429 QUINTON DILLINGHAM PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1430 | 1430 R. M. MOORE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1431 | 1431 RADIUM SPRINGS | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1432 | 1432 RAGLAND STREET | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 38,400
1433 | 1433 RAINBOW DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 40.00 | 1 |  |  |  |
1434 | 1434 RAINBOW DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1435 | 1435 RALSTON PURINA MILLS (Gainesville) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1436 | 1436 RANDALL | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1437 | 1437 RAY MOUNTAIN PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1438 | 1438 RAY MOUNTAIN 2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
1439 | 1439 RAYONIER (Eatonton) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1440 | 1440 RAYONIER (Jesup) | Distribution | Unattended | 115.00 | 13.80 |  | 40.00 | 1 |  |  |  |
1441 | 1441 RAYONIER (Jesup) | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1442 | 1442 REAL DEALS | Distribution | Unattended | 46.00 | 0.60 |  | 2.10 | 1 |  |  |  |
1443 | 1443 REBECCA | Distribution | Unattended | 46.00 | 12.00 |  | 1.50 | 3 |  |  |  |
1444 | 1444 RED DOG FARM ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1445 | 1445 RED TOP MOUNTAIN | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 30,000
1446 | 1446 RED TOP MOUNTAIN | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1447 | 1447 REDMOND CIRCLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1448 | 1448 REDMOND CIRCLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1449 | 1449 REFUGE ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1450 | 1450 REIDS | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1451 | 1451 REIDS PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1452 | 1452 REIDSVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1453 | 1453 REIDSVILLE | Distribution | Unattended | 115.00 | 25.00 |  | 10.00 | 1 |  |  |  |
1454 | 1454 REMERTON | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1455 | 1455 REMLERS CORNER | Distribution | Unattended | 46.00 | 13.80 |  | 20.00 | 1 |  |  |  |
1456 | 1456 REMLERS CORNER | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1457 | 1457 REMLERS CORNER | Distribution | Unattended | 46.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1458 | 1458 RENESSENZ | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1459 | 1459 RENESSENZ | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  |  |  |
1460 | 1460 REST HAVEN | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1461 | 1461 REST HAVEN | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1462 | 1462 RETTCO STEEL | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1463 | 1463 REYNOLDS | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1464 | 1464 RHINE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 2 |  |  |  |
1465 | 1465 RICE CREEK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1466 | 1466 RICHARDSON STREET | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1467 | 1467 RICHMOND HILL | Distribution | Unattended | 115.00 | 13.80 |  | 44.80 | 2 |  |  |  |
1468 | 1468 RIDGEWAY CHURCH ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 120.00 | 2 |  |  |  |
1469 | 1469 RINGGOLD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1470 | 1470 RINGGOLD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1471 | 1471 RISING FAWN | Distribution | Unattended | 46.00 | 12.00 |  | 4.69 | 1 |  |  |  |
1472 | 1472 RITE AID (Newnan) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1473 | 1473 RIVER PARK | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1474 | 1474 RIVER ROAD | Distribution | Unattended | 25.00 | 20.00 |  | 6.25 | 1 |  | Capacitor Bank | 1 | 45,000
1475 | 1475 RIVER ROAD | Distribution | Unattended | 115.00 | 20.00 |  | 45.89 | 1 |  |  |  |
1476 | 1476 RIVER STREET | Distribution | Unattended | 46.00 | 13.80 |  | 120.00 | 3 |  |  |  |
1477 | 1477 RIVERDALE | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1478 | 1478 RIVERDALE | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1479 | 1479 RIVERSIDE MILLS | Distribution | Unattended | 46.00 | 4.00 |  | 14.00 | 2 |  |  |  |
1480 | 1480 RIVERSTONE | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1481 | 1481 RIVERVIEW HYDRO | Generation | Attended | 12.00 | 2.40 |  | 2.00 | 6 |  |  |  |
1482 | 1482 RIVERWOOD #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1483 | 1483 RIVERWOOD #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1484 | 1484 ROBERTS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  | Capacitor Bank | 1 | 45,000
1485 | 1485 ROBERTS ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1486 | 1486 ROBERTS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1487 | 1487 ROBINS AFB #1 | Distribution | Unattended | 115.00 | 12.00 |  | 89.60 | 4 |  |  |  |
1488 | 1488 ROBINS AFB #2 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1489 | 1489 ROBINS AFB #2 | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1490 | 1490 ROBINS AFB #3 | Distribution | Unattended | 12.00 | 4.00 |  | 7.00 | 1 |  |  |  |
1491 | 1491 ROBINS AFB #4 - W.D. Fowler | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1492 | 1492 ROBINS AFB #4 - W.D. Fowler | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1493 | 1493 ROBINS AFB SOLAR (IC-491) | Generation | Attended | 115.00 | 34.50 |  | 145.00 | 1 |  |  |  |
1494 | 1494 ROBINS CT | Generation | Attended | 115.00 | 13.80 |  | 220.00 | 1 |  |  |  |
1495 | 1495 ROCHELLE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1496 | 1496 ROCHELLE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1497 | 1497 ROCKBRIDGE ROAD | Distribution | Unattended | 230.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1498 | 1498 ROCKMART | Distribution | Unattended | 46.00 | 12.00 |  | 15.75 | 3 |  |  |  |
1499 | 1499 ROCKY FORD ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1500 | 1500 ROGERS LANDING PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1501 | 1501 ROME | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  | Capacitor Bank | 1 | 31,500
1502 | 1502 ROME | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1503 | 1503 ROOPVILLE | Distribution | Unattended | 230.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1504 | 1504 ROPER INDUSTRIES #2 (RETIRED) | Distribution | Unattended | 25.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1505 | 1505 ROPER INDUSTRIES (RETIRED) | Distribution | Unattended | 25.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1506 | 1506 ROPERS CORNER | Distribution | Unattended | 115.00 | 12.00 |  | 66.66 | 2 |  | Capacitor Bank | 1 | 30,000
1507 | 1507 ROSSIGNOL HILL | Distribution | Unattended | 46.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1508 | 1508 ROSSIGNOL HILL | Distribution | Unattended | 46.00 | 13.80 |  | 20.00 | 1 |  |  |  |
1509 | 1509 ROSSMAN PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1510 | 1510 ROSWELL | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  | Capacitor Bank | 1 | 45,000
1511 | 1511 ROSWELL | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1512 | 1512 ROTTENWOOD CREEK | Distribution | Unattended | 115.00 | 20.00 |  | 120.00 | 2 |  |  |  |
1513 | 1513 ROYAL ATLANTA | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1514 | 1514 ROYSTON | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1515 | 1515 ROYSTON | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1516 | 1516 ROYSTON MANUFACTURING | Distribution | Unattended | 46.00 | 0.48 |  | 2.10 | 1 |  |  |  |
1517 | 1517 RUCKER BROTHERS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1518 | 1518 RUSSELL AREA PM Retired | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1519 | 1519 SAGE AUTOMOTIVE INTERIORS | Distribution | Unattended | 115.00 | 0.60 |  | 14.00 | 2 |  |  |  |
1520 | 1520 SAINT MARYS | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1521 | 1521 SAINT MARYS ROAD | Distribution | Unattended | 115.00 | 46.00 |  | 60.00 | 1 |  |  |  |
1522 | 1522 SAINT MARYS ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1523 | 1523 SAINT SIMONS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1524 | 1524 SAINT SIMONS | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1525 | 1525 SALE CITY | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1526 | 1526 SALEM GATE | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1527 | 1527 SANDERSON FARMS | Distribution | Unattended | 46.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1528 | 1528 SANDERSVILLE CLAY | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 3 |  |  |  |
1529 | 1529 SANDY BOTTOM | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1530 | 1530 SANDY SPRINGS | Distribution | Unattended | 230.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1531 | 1531 SAPA EXTRUDER | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1532 | 1532 SAPA EXTRUDER | Distribution | Unattended | 46.00 | 0.48 |  | 4.69 | 1 |  |  |  |
1533 | 1533 SARDIS | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1534 | 1534 SARGENT | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1535 | 1535 SASSER | Distribution | Unattended | 46.00 | 12.00 |  | 2.00 | 3 |  |  |  |
1536 | 1536 SATILLA CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1537 | 1537 SAULTER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1538 | 1538 SAVANNAH FOODS | Distribution | Unattended | 46.00 | 4.00 |  | 10.50 | 1 |  |  |  |
1539 | 1539 SCHERER COMMON FACILITIES | Generation | Attended | 500.00 |  |  |  | 3 |  |  |  |
1540 | 1540 SCHERER CONSTRUCTION | Distribution | Attended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1541 | 1541 SCHERER FGD 1/2 | Generation | Attended | 115.00 | 13.80 |  | 300.00 | 4 |  |  |  |
1542 | 1542 SCHERER FGD 3/4 | Generation | Attended | 115.00 | 13.80 |  | 300.00 | 4 |  |  |  |
1543 | 1543 SCHERER FGD 3/4 | Generation | Attended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1544 | 1544 SCHERER FGD 3/4 | Generation | Attended | 115.00 | 4.00 |  | 25.00 | 1 |  |  |  |
1545 | 1545 SCHERER RIVER PUMPING | Distribution | Attended | 115.00 | 4.00 |  | 11.20 | 2 |  |  |  |
1546 | 1546 SCHERER UNIT 1 | Generation | Attended | 500.00 | 25.00 |  | 327.00 | 1 |  |  |  |
1547 | 1547 SCHERER UNIT 1 | Generation | Attended | 500.00 | 25.00 |  | 584.00 | 2 |  |  |  |
1548 | 1548 SCHERER UNIT 1 | Generation | Attended | 25.00 | 4.16 |  | 224.00 | 4 |  |  |  |
1549 | 1549 SCHERER UNIT 2 | Generation | Attended | 25.00 | 4.16 |  | 224.00 | 4 |  |  |  |
1550 | 1550 SCHERER UNIT 2 | Generation | Attended | 500.00 | 25.00 |  | 876.00 | 3 |  |  |  |
1551 | 1551 SCHERER UNIT 3 | Generation | Attended | 25.00 | 4.16 | 7 | 56.00 | 1 |  |  |  |
1552 | 1552 SCHERER UNIT 3 | Generation | Attended | 25.00 | 4.16 | 4 | 56.00 | 1 |  |  |  |
1553 | 1553 SCHERER UNIT 3 | Generation | Attended | 500.00 | 25.00 |  | 876.00 | 3 |  |  |  |
1554 | 1554 SCHERER UNIT 4 | Generation | Attended | 500.00 | 25.00 |  | 981.00 | 3 |  |  |  |
1555 | 1555 SCHERER UNIT 4 | Generation | Attended | 25.00 | 4.16 |  | 112.00 | 2 |  |  |  |
1556 | 1556 SCHERER UNIT 4 | Generation | Attended | 25.00 | 4.16 |  | 33.60 | 1 |  |  |  |
1557 | 1557 SCOTT HUDGENS BUILDING | Distribution | Unattended | 20.00 | 0.48 |  | 1.12 | 1 |  |  |  |
1558 | 1558 SCOTTDALE | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  | Capacitor Bank | 3 | 185,000
1559 | 1559 SCOTTDALE | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1560 | 1560 SCOVILLE MANUFACTURING | Distribution | Unattended | 46.00 | 0.48 |  | 4.48 | 2 |  |  |  |
1561 | 1561 SCOVILLE MANUFACTURING | Distribution | Unattended | 46.00 | 0.48 |  | 2.15 | 1 |  |  |  |
1562 | 1562 SEA ISLAND | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1563 | 1563 SEALY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1564 | 1564 SEARS FASHION CENTER 25/4 KV | Distribution | Unattended | 25.00 | 4.00 |  | 2.80 | 1 |  |  |  |
1565 | 1565 SEVENTH AVENUE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1566 | 1566 SEVENTH AVENUE | Distribution | Unattended | 115.00 | 25.00 |  | 80.00 | 2 |  |  |  |
1567 | 1567 SEWELL ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1568 | 1568 SHARON PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1569 | 1569 SHAW INDUSTRIES #2 PD (Trenton) | Distribution | Unattended | 46.00 |  |  | 5.00 | 1 |  |  |  |
1570 | 1570 SHAW INDUSTRIES (Milledgeville) | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1571 | 1571 SHAW INDUSTRIES (Milledgeville) | Distribution | Unattended | 12.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1572 | 1572 SHAW INDUSTRIES (Thomson) | Distribution | Unattended | 115.00 | 4.00 |  | 37.50 | 4 |  |  |  |
1573 | 1573 SHAW INDUSTRIES (Thomson) | Distribution | Unattended | 115.00 | 4.00 |  | 22.40 | 1 |  |  |  |
1574 | 1574 SHENANDOAH SEWAGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1575 | 1575 SHENANDOAH SEWAGE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1576 | 1576 SHILOH | Distribution | Unattended | 115.00 | 25.00 |  | 21.00 | 2 |  |  |  |
1577 | 1577 SHURLING DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 2 |  |  |  |
1578 | 1578 SHURLING DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1579 | 1579 SILGAN PLASTICS | Distribution | Unattended | 46.00 | 4.00 |  | 5.00 | 1 |  |  |  |
1580 | 1580 SILK HOPE | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1581 | 1581 SIMPSON LUMBER | Distribution | Unattended | 46.00 | 13.80 |  | 7.00 | 1 |  |  |  |
1582 | 1582 SINCLAIR DAM HYDRO | Generation | Attended | 115.00 | 6.60 |  | 50.00 | 2 |  |  |  |
1583 | 1583 SINCLAIR DAM HYDRO | Generation | Attended | 6.60 | 0.60 |  | 1.00 | 2 |  |  |  |
1584 | 1584 SIX MILE | Distribution | Unattended | 115.00 | 25.00 |  | 44.80 | 2 |  |  |  |
1585 | 1585 SIX MILE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1586 | 1586 SKIDAWAY ISLAND | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1587 | 1587 SKIDAWAY ISLAND | Distribution | Unattended | 115.00 | 25.00 |  | 67.20 | 2 |  |  |  |
1588 | 1588 SLAPPEY DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  | Capacitor Bank | 1 | 45,000
1589 | 1589 SMITHVILLE | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1590 | 1590 SMITHVILLE | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1591 | 1591 SMITHVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1592 | 1592 SMYRNA | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  | Capacitor Bank | 1 | 45,000
1593 | 1593 SMYRNA | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1594 | 1594 SNAPFINGER ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1595 | 1595 SOCIAL CIRCLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1596 | 1596 SOCIAL CIRCLE | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1597 | 1597 SOCIAL CIRCLE PRIMARY | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  | Capacitor Bank | 3 | 60,600
1598 | 1598 SOCIAL CIRCLE PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 10.00 | 1 |  |  |  |
1599 | 1599 SOCIAL CIRCLE PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
1600 | 1600 SOCIAL CIRCLE PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1601 | 1601 SOLO CUP #1 | Distribution | Unattended | 46.00 | 0.48 |  | 5.25 | 1 |  |  |  |
1602 | 1602 SOLO CUP #1 | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1603 | 1603 SOLO CUP #1 | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 1 |  |  |  |
1604 | 1604 SOLVAY ADVANCED POLYMERS | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
1605 | 1605 SOPERTON PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1606 | 1606 SOUTH ADEL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1607 | 1607 SOUTH ATHENS | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1608 | 1608 SOUTH AUGUSTA | Transmission | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  | Capacitor Bank | 2 | 119,000
1609 | 1609 SOUTH AUGUSTA | Transmission | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1610 | 1610 SOUTH CHATTOOGA | Transmission | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1611 | 1611 SOUTH CHATTOOGA | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1612 | 1612 SOUTH CLEVELAND | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  | Capacitor Bank | 2 | 30,000
1613 | 1613 SOUTH COBB DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 80.00 | 2 |  |  |  |
1614 | 1614 SOUTH COLUMBUS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 150,000
1615 | 1615 SOUTH DAHLONEGA | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1616 | 1616 SOUTH EFFINGHAM | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1617 | 1617 SOUTH GAINESVILLE | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1618 | 1618 SOUTH GAINESVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 12.07 | 1 |  |  |  |
1619 | 1619 SOUTH GEORGETOWN PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1620 | 1620 SOUTH GEORGIA METHODIST NURSING HOME | Distribution | Unattended | 46.00 | 0.48 |  | 3.36 | 6 |  |  |  |
1621 | 1621 SOUTH MACON | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 2 | 91,800
1622 | 1622 SOUTH MACON | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1623 | 1623 SOUTH MADISON | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1624 | 1624 SOUTH MADISON | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1625 | 1625 SOUTH MCRAE | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
1626 | 1626 SOUTH NORCROSS | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1627 | 1627 SOUTH NORCROSS | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1628 | 1628 SOUTH NORCROSS | Distribution | Unattended | 115.00 | 25.00 |  | 22.40 | 1 |  |  |  |
1629 | 1629 SOUTH OGLETHORPE | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1630 | 1630 SOUTH OGLETHORPE | Distribution | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1631 | 1631 SOUTH RIVER WASTEWATER TREATMENT | Distribution | Unattended | 20.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1632 | 1632 SOUTH TIFTON | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1633 | 1633 SOUTH VILLA RICA | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1634 | 1634 SOUTH VILLA RICA | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1635 | 1635 SOUTHEAST TOYOTA | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1636 | 1636 SOUTHEAST WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1637 | 1637 SOUTHEAST WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1638 | 1638 SOUTHEASTERN ASSEMBLY | Distribution | Unattended | 46.00 | 0.48 |  | 3.36 | 2 |  |  |  |
1639 | 1639 SOUTHEASTERN REG RES LAB | Distribution | Unattended | 12.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1640 | 1640 SOUTHERN BELL | Distribution | Unattended | 13.20 | 0.48 |  | 3.00 | 2 |  |  |  |
1641 | 1641 SOUTHERN GATEWAY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1642 | 1642 SOUTHERN LNG | Distribution | Unattended | 115.00 | 34.50 |  | 480.00 | 4 |  |  |  |
1643 | 1643 SOUTHERN LNG | Distribution | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
1644 | 1644 SOUTHERN MILLS #1 (Senoia) | Distribution | Unattended | 46.00 | 0.60 |  | 2.50 | 3 |  |  |  |
1645 | 1645 SOUTHERN MILLS #2 (Senoia) | Distribution | Unattended | 46.00 | 0.60 |  | 3.50 | 1 |  |  |  |
1646 | 1646 SOUTHERN MILLS (Zebulon) | Distribution | Unattended | 46.00 | 0.60 |  | 2.80 | 1 |  |  |  |
1647 | 1647 SOUTHERN NATURAL GAS (Ellerslie) | Distribution | Unattended | 230.00 | 4.00 |  |  | 1 |  |  |  |
1648 | 1648 SOUTHERN NATURAL GAS (Ellerslie) | Distribution | Unattended | 230.00 | 4.00 |  | 25.00 | 1 |  |  |  |
1649 | 1649 SOUTHERN NATURAL GAS (Fairburn) | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1650 | 1650 SOUTHERN RAILWAY | Distribution | Unattended | 12.00 | 2.40 |  | 2.80 | 3 |  |  |  |
1651 | 1651 SOUTHERN RAILWAY (Inman Yards) | Distribution | Unattended | 20.00 | 2.40 |  | 7.00 | 2 |  |  |  |
1652 | 1652 SOUTHERN STATES CO-OP | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1653 | 1653 SOUTHERN WOOD SUPPLIES | Distribution | Unattended | 46.00 | 0.60 |  | 7.00 | 1 |  | Capacitor Bank | 1 | 5,400
1654 | 1654 SOUTHERN WOOD SUPPLIES | Distribution | Unattended | 46.00 | 4.00 |  | 5.25 | 1 |  |  |  |
1655 | 1655 SOUTHWEST DUBLIN | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1656 | 1656 SOUTHWIRE | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1657 | 1657 SOUTHWIRE #2 | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1658 | 1658 SPALDING | Distribution | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
1659 | 1659 SPALDING | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1660 | 1660 SPALDING DRIVE | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1661 | 1661 SPALDING DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1662 | 1662 SPARTA #2 | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1663 | 1663 SPIRIT CREEK | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1664 | 1664 SPIVEY LAKE | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1665 | 1665 SPRING STREET | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1666 | 1666 SPRING STREET | Distribution | Unattended | 115.00 | 20.00 |  | 120.00 | 2 |  |  |  |
1667 | 1667 SPRING STREET | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1668 | 1668 SPRINGFIELD | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1669 | 1669 STANDRIDGE COLOR #1 | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1670 | 1670 STANDRIDGE COLOR #1 | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1671 | 1671 STANDRIDGE COLOR #18 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1672 | 1672 STANDRIDGE COLOR #2 | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1673 | 1673 STANTON SPRINGS | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1674 | 1674 STATE HIGHWAY TESTING LAB | Distribution | Unattended | 25.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1675 | 1675 STATENVILLE PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
1676 | 1676 STATESBORO | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1677 | 1677 STATESBORO | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1678 | 1678 STATESBORO AREA #8 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1679 | 1679 STATESBORO PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 27.48 | 1 |  | Capacitor Bank | 2 | 62,400
1680 | 1680 STATESBORO PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1681 | 1681 STATESBORO PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1682 | 1682 STATHAM | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1683 | 1683 STEEPLECHASE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.33 | 1 |  |  |  |
1684 | 1684 STEVENS CREEK | Transmission | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1685 | 1685 STILESBORO | Distribution | Unattended | 46.00 | 12.00 |  | 10.50 | 2 |  |  |  |
1686 | 1686 STOCKBRIDGE | Transmission | Unattended | 230.00 | 115.00 |  | 300.00 | 1 |  | Capacitor Bank | 1 | 45,000
1687 | 1687 STOCKBRIDGE | Transmission | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1688 | 1688 STOCKBRIDGE | Transmission | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1689 | 1689 STOKES LAKE PD | Distribution | Unattended | 46.00 | 25.00 |  | 5.00 | 1 |  |  |  |
1690 | 1690 STONE MOUNTAIN | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1691 | 1691 STONEWALL STREET | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1692 | 1692 STONEY BROOK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1693 | 1693 STOWE WOODWARD | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1694 | 1694 STUBBS ROAD PM | Distribution | Unattended | 46.00 | 7.20 |  |  | 1 |  |  |  |
1695 | 1695 SUMMER LAKE | Distribution | Unattended | 230.00 | 25.00 |  | 300.00 | 5 |  |  |  |
1696 | 1696 SUMMERVILLE PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 9.38 | 1 |  | Capacitor Bank | 3 | 76,800
1697 | 1697 SUMMERVILLE PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 12.32 | 1 |  |  |  |
1698 | 1698 SUMMERVILLE PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 40.00 | 1 |  |  |  |
1699 | 1699 SUMNER | Distribution | Unattended | 46.00 | 12.00 |  | 5.60 | 1 |  |  |  |
1700 | 1700 SUNDANCE PRODUCTS | Distribution | Unattended | 46.00 | 0.48 |  | 6.25 | 1 |  |  |  |
1701 | 1701 SUNSHINE BISCUIT (Columbus) | Distribution | Unattended | 12.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1702 | 1702 SUNSHINE BISCUIT (Columbus) | Distribution | Unattended | 12.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1703 | 1703 SUPER SOD FARM PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1704 | 1704 SUTTONS CROSSROAD | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1705 | 1705 SUWANEE | Transmission | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  | Capacitor Bank | 3 | 210,000
1706 | 1706 SUWANEE | Transmission | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1707 | 1707 SWAINSBORO AREA #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1708 | 1708 SWAINSBORO AREA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1709 | 1709 SWAINSBORO AREA #5 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.28 | 1 |  |  |  |
1710 | 1710 SWAINSBORO PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 25,000
1711 | 1711 SWAINSBORO PRIMARY | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1712 | 1712 SWEET CITY PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
1713 | 1713 SWEETBOTTOM | Distribution | Unattended | 230.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1714 | 1714 SWEETBOTTOM | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1715 | 1715 SWEETWATER PAPER BOARD | Distribution | Unattended | 46.00 | 0.60 |  | 21.00 | 3 |  |  |  |
1716 | 1716 SWIFT SPINNING MILLS #2 | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1717 | 1717 SYLVESTER PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 29.56 | 1 |  |  |  |
1718 | 1718 TALLAPOOSA | Distribution | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1719 | 1719 TALLAPOOSA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1720 | 1720 TALLASSEE ROAD SCHOOL PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1721 | 1721 TALLULAH FALLS | Generation | Attended | 115.00 | 6.60 |  | 12.00 | 1 |  |  |  |
1722 | 1722 TALLULAH FALLS | Generation | Attended | 115.00 | 6.60 |  | 16.00 | 1 |  |  |  |
1723 | 1723 TALLULAH FALLS | Generation | Attended | 115.00 | 6.60 |  | 16.00 | 1 |  |  |  |
1724 | 1724 TALLULAH FALLS | Generation | Attended | 115.00 | 6.60 |  | 17.92 | 1 |  |  |  |
1725 | 1725 TALLULAH FALLS | Generation | Attended | 115.00 | 6.60 |  | 35.84 | 2 |  |  |  |
1726 | 1726 TALMO TAP PD | Distribution | Unattended | 46.00 | 12.00 |  |  | 1 |  |  |  |
1727 | 1727 TALONA PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1728 | 1728 TANNER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1729 | 1729 TANYARD CREEK PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1730 | 1730 TARA | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1731 | 1731 TARVER | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1732 | 1732 TATUM ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1733 | 1733 TAYLORSVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1734 | 1734 TAZEWELL | Transmission | Unattended | 230.00 | 46.00 |  | 40.00 | 1 |  |  |  |
1735 | 1735 TEMPERANCE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1736 | 1736 TEMPLE | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1737 | 1737 TEMPLE INDUSTRIES (Thomson) | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  |  |  |
1738 | 1738 TEMPLE INDUSTRIES (Thomson) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1739 | 1739 TENNECO AUTOMOTIVE | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1740 | 1740 TENNILLE CITY | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1741 | 1741 TERRORA | Distribution | Unattended | 46.00 | 12.00 | 7 | 10.50 | 1 |  |  |  |
1742 | 1742 TERRORA HYDRO | Generation | Attended | 115.00 | 6.60 |  | 30.00 | 1 |  |  |  |
1743 | 1743 TERRORA HYDRO | Generation | Attended | 115.00 | 46.00 |  | 44.80 | 2 |  |  |  |
1744 | 1744 TEXAS VALLEY | Distribution | Unattended | 115.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1745 | 1745 TEXTRON SPECIALITY PRODUCTS | Distribution | Unattended | 115.00 | 13.80 |  | 22.40 | 1 |  |  |  |
1746 | 1746 THALMANN | Transmission | Unattended | 500.00 |  |  |  | 3 |  |  |  |
1747 | 1747 THALMANN STATION SERVICE | Distribution | Unattended | 115.00 | 12.00 |  | 9.37 | 2 |  |  |  |
1748 | 1748 THE BRIDGE CHURCH | Distribution | Unattended | 25.00 | 0.48 |  | 2.10 | 1 |  |  |  |
1749 | 1749 THE ROCK | Distribution | Unattended | 25.00 | 0.48 |  | 12.50 | 4 |  |  |  |
1750 | 1750 THE ROCK | Distribution | Unattended | 230.00 | 25.00 |  | 22.40 | 1 |  |  |  |
1751 | 1751 THIELE KAOLIN (Limestone Creek) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1752 | 1752 THIELE KAOLIN (Mine) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1753 | 1753 THIELE KAOLIN (Sandersville) | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1754 | 1754 THIELE KAOLIN (Sandersville) | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1755 | 1755 THIELE KAOLIN (Wrens) | Distribution | Unattended | 46.00 | 4.00 |  | 6.25 | 1 |  |  |  |
1756 | 1756 THIELE KAOLIN (Wrens) | Distribution | Unattended | 46.00 | 4.00 |  | 14.00 | 2 |  |  |  |
1757 | 1757 THOMASTON | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  | Capacitor Bank | 1 | 30,000
1758 | 1758 THOMASTON | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1759 | 1759 THOMASTON | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1760 | 1760 THOMPSON BRIDGE | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 2 |  |  |  |
1761 | 1761 THOMSON AREA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1762 | 1762 THOMSON AREA #8 PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1763 | 1763 THOMSON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  | Capacitor Bank | 2 | 43,800
1764 | 1764 THOMSON PRIMARY | Transmission | Unattended | 13.80 | 0.48 |  | 1.00 | 1 |  |  |  |
1765 | 1765 THOMSON PRIMARY | Transmission | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1766 | 1766 THRALL CAR MANUFACTURING | Distribution | Unattended | 25.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1767 | 1767 THREE RIVERS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1768 | 1768 TIFTON PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  | Capacitor Bank | 1 | 10,800
1769 | 1769 TILLY MILL | Distribution | Unattended | 230.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1770 | 1770 TIMBERMEN #1 (Warrenton) | Distribution | Unattended | 46.00 | 0.48 |  | 1.68 | 1 |  |  |  |
1771 | 1771 TIMBERMEN (Camak) | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1772 | 1772 TIN BRIDGE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1773 | 1773 TIOGA | Transmission | Unattended | 230.00 | 46.00 |  | 60.00 | 1 |  | Capacitor Bank | 1 | 7,800
1774 | 1774 TNS MILLS | Distribution | Unattended | 115.00 | 25.00 |  | 31.50 | 3 |  |  |  |
1775 | 1775 TOCCOA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  | Capacitor Bank | 1 | 31,500
1776 | 1776 TODD MARSHALL PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1777 | 1777 TODD MARSHALL PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1778 | 1778 TOLLESON LUMBER (Perry) | Distribution | Unattended | 46.00 | 0.48 |  | 5.60 | 3 |  |  |  |
1779 | 1779 TOM HUSTON PEANUT (Bakery) | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1780 | 1780 TOMMY FIELDS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.28 | 1 |  |  |  |
1781 | 1781 TOTAL SYSTEM SERVICES | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1782 | 1782 TOTO | Distribution | Unattended | 25.00 | 4.00 |  | 7.00 | 1 |  |  |  |
1783 | 1783 TOWNSEND | Distribution | Unattended | 115.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1784 | 1784 TOYO | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1785 | 1785 TRANQUILLA HILL | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1786 | 1786 TRANSCO | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1787 | 1787 TRANSCO | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1788 | 1788 TRENCH SHORING SERVICES | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1789 | 1789 TRENT TUBE | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1790 | 1790 TRENTON | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1791 | 1791 TRENTON | Distribution | Unattended | 46.00 | 25.00 |  | 21.00 | 3 |  |  |  |
1792 | 1792 TRENTON | Distribution | Unattended | 46.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1793 | 1793 TRENTON | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
1794 | 1794 TREUTLEN | Distribution | Unattended | 115.00 | 25.00 |  | 100.00 | 2 |  | Capacitor Bank | 1 | 36,000
1795 | 1795 TRI COUNTY FARMS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1796 | 1796 TRIBUTARY | Transmission | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1797 | 1797 TRINITY INDUSTRIES | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 3 |  |  |  |
1798 | 1798 TRION | Distribution | Unattended | 115.00 | 12.00 |  | 50.00 | 2 |  |  |  |
1799 | 1799 TRIPPS BEACH PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.28 | 1 |  |  |  |
1800 | 1800 TRONOX | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1801 | 1801 TROUP CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 2 |  |  |  |
1802 | 1802 TROUP CREEK | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1803 | 1803 TROY ALDRIDGE PM | Distribution | Unattended | 46.00 | 0.48 |  | 0.15 | 1 |  |  |  |
1804 | 1804 TRUMAN PARKWAY | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1805 | 1805 TRUMAN PARKWAY | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1806 | 1806 TUCKER | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1807 | 1807 TUCKER | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1808 | 1808 TUGALO | Generation | Attended | 115.00 | 6.60 |  | 80.00 | 2 |  |  |  |
1809 | 1809 TURPIN HILL | Distribution | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  |  |  |
1810 | 1810 TWILIGHT | Distribution | Unattended | 115.00 | 25.00 |  | 56.00 | 1 |  |  |  |
1811 | 1811 TWIN CITY | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1812 | 1812 TWIN LAKES | Transmission | Unattended | 115.00 | 69.00 |  | 60.00 | 1 |  |  |  |
1813 | 1813 TWIN LAKES | Transmission | Unattended | 115.00 | 69.00 | 13 | 60.00 | 1 |  |  |  |
1814 | 1814 TWIN PINES | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1815 | 1815 TY TY PD | Distribution | Unattended | 46.00 | 12.00 |  | 5.00 | 1 |  |  |  |
1816 | 1816 TYBEE ISLAND | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1817 | 1817 TYBEE ISLAND | Distribution | Unattended | 46.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1818 | 1818 TYCO PLASTICS #1 | Distribution | Unattended | 46.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1819 | 1819 TYCO PLASTICS #11 PD | Distribution | Unattended | 46.00 |  |  | 2.50 | 1 |  |  |  |
1820 | 1820 TYCO PLASTICS #12 PD | Distribution | Unattended | 46.00 |  |  | 2.50 | 1 |  |  |  |
1821 | 1821 TYCO PLASTICS #8 | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1822 | 1822 TYSON FOODS (Cumming) | Distribution | Unattended | 12.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1823 | 1823 TYSON FOODS (Cumming) | Distribution | Unattended | 12.00 | 0.48 |  | 6.25 | 1 |  |  |  |
1824 | 1824 U.S. CAN (Tallapoosa) | Distribution | Unattended | 46.00 | 0.48 |  | 3.50 | 1 |  |  |  |
1825 | 1825 U.S. MARINE CORPS (MOCK ROAD) | Distribution | Unattended | 115.00 | 34.50 |  | 40.00 | 1 |  |  |  |
1826 | 1826 U.S. MARINE CORPS SUPPLY DEPOT | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1827 | 1827 U.S. MARINE CORPS SUPPLY DEPOT | Distribution | Unattended | 34.50 | 12.00 |  | 25.00 | 1 |  |  |  |
1828 | 1828 U.S. POSTAL FACILITY (Hapeville) | Distribution | Unattended | 20.00 | 4.00 |  | 5.00 | 1 |  |  |  |
1829 | 1829 U.S. POSTAL SERVICE | Distribution | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1830 | 1830 U.S. VETERANS HOSPITAL (Dublin) | Distribution | Unattended | 46.00 | 4.00 |  | 14.00 | 2 |  |  |  |
1831 | 1831 U.S. VETERANS HOSPITAL (Dublin) | Distribution | Unattended | 12.00 | 4.00 |  | 5.00 | 1 |  |  |  |
1832 | 1832 UNILEVER | Distribution | Unattended | 20.00 | 4.00 |  | 4.69 | 1 |  |  |  |
1833 | 1833 UNIMIN | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1834 | 1834 UNION POINT AREA #1 PM (RETIRED) | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1835 | 1835 UNION POINT PRIMARY | Transmission | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  | Capacitor Bank | 2 | 40,800
1836 | 1836 UNION POINT PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1837 | 1837 UNITED PARCEL SERVICE | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 2 |  |  |  |
1838 | 1838 UNIVERSITY CENTER | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1839 | 1839 UNIVERSITY OF GEORGIA | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1840 | 1840 UNIVERSITY OF GEORGIA | Distribution | Unattended | 115.00 | 12.00 |  | 80.00 | 2 |  |  |  |
1841 | 1841 UNIVERSITY OF WEST GEORGIA | Distribution | Unattended | 46.00 | 12.00 |  | 10.00 | 1 |  |  |  |
1842 | 1842 UNIVETER CROSSING | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  |  |  |
1843 | 1843 UPS DATA CENTER (Alpharetta) | Distribution | Unattended | 25.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1844 | 1844 US 1 RECYCLING | Distribution | Unattended | 46.00 | 4.00 |  | 4.69 | 1 |  |  |  |
1845 | 1845 UVALDA | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1846 | 1846 VALDOSTA | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  | Capacitor Bank | 2 | 60,000
1847 | 1847 VALLEY HILL ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
1848 | 1848 VARNELL | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1849 | 1849 VARNELL | Distribution | Unattended | 115.00 | 12.00 |  | 6.25 | 1 |  |  |  |
1850 | 1850 VENUS THREAD | Distribution | Unattended | 46.00 | 0.60 |  | 5.75 | 3 |  |  |  |
1851 | 1851 VERDERY STREET | Distribution | Unattended | 115.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1852 | 1852 VICTORY DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1853 | 1853 VICTORY DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1854 | 1854 VIDALIA | Distribution | Unattended | 115.00 | 46.00 |  | 56.00 | 1 |  | Capacitor Bank | 1 | 117,000
1855 | 1855 VIDALIA | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1856 | 1856 VIENNA PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
1857 | 1857 VIENNA PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1858 | 1858 VIENNA PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1859 | 1859 VILLA RICA PRIMARY | Transmission | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1860 | 1860 VINEVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  |  |  |
1861 | 1861 VINSON ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1862 | 1862 VIRGINIA AVENUE | Distribution | Unattended | 230.00 | 20.00 |  | 120.00 | 2 |  |  |  |
1863 | 1863 VISY PAPER | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1864 | 1864 VOGTLE 1&2 | Generation | Attended | 500.00 | 25.00 |  | 1356.00 | 3 | 1 | Capacitor Bank | 2 | 180,000
1865 | 1865 VOGTLE 1&2 | Generation | Attended | 500.00 | 25.00 |  | 1356.00 | 3 | 1 |  |  |
1866 | 1866 VOGTLE 1&2 | Generation | Attended | 25.00 | 1.00 |  | 17.14 | 2 | 1 |  |  |
1867 | 1867 VOGTLE 1&2 | Generation | Attended | 25.00 | 1.00 |  | 17.14 | 2 | 1 |  |  |
1868 | 1868 VOGTLE 1&2 | Generation | Attended | 230.00 | 25.00 |  | 1864.00 | 4 | 1 |  |  |
1869 | 1869 VOGTLE 1&2 | Generation | Attended | 230.00 | 25.00 |  | 1864.00 | 4 | 1 |  |  |
1870 | 1870 VOGTLE 1&2 | Generation | Attended | 25.00 | 13.80 |  | 336.00 | 6 | 1 |  |  |
1871 | 1871 VOGTLE 1&2 | Generation | Attended | 13.80 | 4.00 |  | 12.50 | 1 | 1 |  |  |
1872 | 1872 VOGTLE 1&2 | Generation | Attended | 13.80 | 4.00 |  | 12.50 | 1 | 1 |  |  |
1873 | 1873 VOGTLE 1&2 | Generation | Attended | 25.00 | 13.80 |  | 336.00 | 6 | 1 |  |  |
1874 | 1874 VOGTLE 1&2 | Generation | Attended | 500.00 |  |  |  | 3 | 1 |  |  |
1875 | 1875 VOGTLE 1&2 | Generation | Attended | 500.00 |  |  |  | 3 | 1 |  |  |
1876 | 1876 VOGTLE 1&2 | Generation | Attended | 230.00 | 13.80 |  | 134.40 | 2 | 1 |  |  |
1877 | 1877 VOGTLE 1&2 | Generation | Attended | 230.00 | 13.80 |  | 134.40 | 2 | 1 |  |  |
1878 | 1878 VOGTLE 230KV SWITCHING | Transmission | Unattended | 230.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1879 | 1879 VOGTLE 3&4 500KV | Generation | Attended | 500.00 | 25.00 |  | 1840.00 | 4 |  |  |  |
1880 | 1880 VOGTLE 3&4 500KV | Generation | Attended | 25.00 | 1.00 |  | 20.00 | 2 |  |  |  |
1881 | 1881 VOGTLE 3&4 500KV | Generation | Attended | 6.60 | 0.48 |  | 1.00 | 1 |  |  |  |
1882 | 1882 VOGTLE 3&4 500KV | Generation | Attended | 230.00 | 25.00 |  | 1840.00 | 4 |  |  |  |
1883 | 1883 VOGTLE 3&4 500KV | Generation | Attended | 500.00 |  |  |  | 3 |  |  |  |
1884 | 1884 VULCAN MATERIALS (Columbus) | Distribution | Unattended | 25.00 | 2.40 |  | 4.20 | 1 |  |  |  |
1885 | 1885 VULCAN MATERIALS (Grayson) | Distribution | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1886 | 1886 VULCAN MATERIALS (Lithia Springs) | Distribution | Unattended | 46.00 | 2.40 |  | 14.00 | 2 |  |  |  |
1887 | 1887 VULCAN MATERIALS (Lithonia) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1888 | 1888 VULCAN MATERIALS (Madras) | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1889 | 1889 VULCAN MATERIALS (Norcross) | Distribution | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1890 | 1890 W. G. JOHNSON PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1891 | 1891 W. L. BONNELL #1 | Distribution | Unattended | 46.00 | 0.48 |  | 5.60 | 2 |  |  |  |
1892 | 1892 W. L. BONNELL #2 | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 2 |  |  |  |
1893 | 1893 W. L. BONNELL #3 | Distribution | Unattended | 46.00 | 0.48 |  | 1.12 | 3 |  |  |  |
1894 | 1894 W. M. WRIGLEY | Distribution | Unattended | 115.00 | 4.00 |  | 42.00 | 4 |  |  |  |
1895 | 1895 W. S. CATRETT PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1896 | 1896 WABASH | Distribution | Unattended | 230.00 | 20.00 |  | 112.00 | 2 |  |  |  |
1897 | 1897 WABASH | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1898 | 1898 WACO | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1899 | 1899 WALKER CO. INDUSTRIAL PARK | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1900 | 1900 WALLACE DAM | Generation | Attended | 230.00 | 13.80 |  | 390.00 | 2 |  |  |  |
1901 | 1901 WALLACE DAM | Generation | Attended | 14.40 | 0.48 |  |  | 1 |  |  |  |
1902 | 1902 WALLACE DAM | Generation | Attended | 14.40 | 0.48 |  | 5.04 | 3 |  |  |  |
1903 | 1903 WALMART | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1904 | 1904 WALTHOURVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1905 | 1905 WALTHOURVILLE | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1906 | 1906 WANSLEY | Generation | Attended | 13.80 | 4.00 |  | 21.00 | 2 | 1 |  |  |
1907 | 1907 WANSLEY | Generation | Attended | 4.00 | 0.48 |  | 1.12 | 2 | 1 |  |  |
1908 | 1908 WANSLEY FGD | Generation | Attended | 230.00 | 13.80 |  | 120.00 | 2 |  |  |  |
1909 | 1909 WANSLEY PUMPING | Distribution | Unattended | 115.00 | 4.00 |  | 11.20 | 2 |  |  |  |
1910 | 1910 WANSLEY PUMPING | Distribution | Unattended | 115.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1911 | 1911 WARM SPRINGS ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 50.00 | 1 |  |  |  |
1912 | 1912 WARRENTON | Distribution | Unattended | 46.00 | 8.00 |  | 28.00 | 4 |  |  |  |
1913 | 1913 WARRENTON AREA #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1914 | 1914 WARRENTON AREA #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1915 | 1915 WARRENTON AREA #3 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1916 | 1916 WARRENTON AREA #5 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1917 | 1917 WARRENTON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  | Capacitor Bank | 2 | 60,000
1918 | 1918 WARRENTON PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1919 | 1919 WASHINGTON | Distribution | Unattended | 115.00 | 12.00 |  | 41.70 | 1 |  | Capacitor Bank | 2 | 25,200
1920 | 1920 WATKINS WOODS PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1921 | 1921 WAVERLY PRIMARY | Transmission | Unattended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
1922 | 1922 WAVERLY PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1923 | 1923 WAX | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1924 | 1924 WAX | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1925 | 1925 WAYCROSS | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1926 | 1926 WAYCROSS MOULDED PRODUCTS | Distribution | Unattended | 12.00 | 0.48 |  | 2.80 | 1 |  |  |  |
1927 | 1927 WAYNE FARMS | Distribution | Unattended | 46.00 | 0.48 |  | 7.00 | 1 |  |  |  |
1928 | 1928 WAYNESBORO | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1929 | 1929 WAYNESBORO PRIMARY | Transmission | Unattended | 115.00 | 46.00 |  | 25.00 | 1 |  |  |  |
1930 | 1930 WELCOME ALL ROAD | Distribution | Unattended | 230.00 | 25.00 |  | 120.00 | 2 |  |  |  |
1931 | 1931 WELLS ALUMINUM #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1932 | 1932 WELLS ALUMINUM #2 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1933 | 1933 WESLEYAN DRIVE | Distribution | Unattended | 115.00 | 4.00 |  | 7.00 | 1 |  |  |  |
1934 | 1934 WESLEYAN DRIVE | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1935 | 1935 WEST 11TH STREET | Distribution | Unattended | 115.00 | 12.00 |  | 21.00 | 2 |  |  |  |
1936 | 1936 WEST ATHENS | Distribution | Unattended | 115.00 | 12.00 |  | 44.80 | 2 |  |  |  |
1937 | 1937 WEST AUGUSTA | Distribution | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 60,500
1938 | 1938 WEST CRAWFORDVILLE | Distribution | Unattended | 46.00 | 25.00 |  | 7.00 | 1 |  |  |  |
1939 | 1939 WEST DALLAS | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1940 | 1940 WEST DALLAS | Distribution | Unattended | 115.00 | 46.00 |  | 22.40 | 1 |  |  |  |
1941 | 1941 WEST DALLAS | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1942 | 1942 WEST DICKEY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1943 | 1943 WEST DICKEY PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.50 | 2 |  |  |  |
1944 | 1944 WEST DUBLIN | Distribution | Unattended | 230.00 | 12.00 |  | 67.20 | 2 |  |  |  |
1945 | 1945 WEST END | Distribution | Unattended | 115.00 | 20.00 |  | 100.00 | 2 |  |  |  |
1946 | 1946 WEST GRIFFIN | Distribution | Unattended | 46.00 | 12.00 |  | 14.00 | 2 |  | Capacitor Bank | 1 | 6
1947 | 1947 WEST MABLETON | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1948 | 1948 WEST MOULTRIE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1949 | 1949 WEST POINT FOUNDRY & MACHINE | Distribution | Unattended | 12.00 | 0.60 |  | 2.80 | 3 |  |  |  |
1950 | 1950 WEYERHAEUSER (Colbert) | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
1951 | 1951 WEYERHAEUSER (Savannah) | Distribution | Unattended | 46.00 | 13.80 |  | 33.60 | 1 |  |  |  |
1952 | 1952 WHEELER ROAD | Distribution | Unattended | 230.00 | 12.00 |  | 33.60 | 1 |  |  |  |
1953 | 1953 WHIRLWIND STEEL PD | Distribution | Unattended | 46.00 | 0.48 |  | 2.50 | 1 |  |  |  |
1954 | 1954 WHITE PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1955 | 1955 WHITE BLUFF | Transmission | Unattended | 115.00 | 13.80 |  | 50.00 | 2 |  | Capacitor Bank | 1 | 45,000
1956 | 1956 WHITEHALL | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1957 | 1957 WHITEMARSH ISLAND | Distribution | Unattended | 115.00 | 13.80 |  | 25.00 | 1 |  |  |  |
1958 | 1958 WHITEMARSH ISLAND | Distribution | Unattended | 115.00 | 13.80 |  | 14.00 | 1 |  |  |  |
1959 | 1959 WHITEOAK | Transmission | Unattended | 115.00 | 12.00 |  | 67.20 | 3 |  |  |  |
1960 | 1960 WHITEOAK | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  |  |  |
1961 | 1961 WHITESBURG | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1962 | 1962 WHITESTONE PD | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1963 | 1963 WHITESTONE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
1964 | 1964 WHITEWATER | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1965 | 1965 WIEUCA ROAD | Distribution | Unattended | 230.00 | 20.00 |  | 60.00 | 1 |  |  |  |
1966 | 1966 WILDER ROAD PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1967 | 1967 WILLACOOCHEE CITY | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1968 | 1968 WILLIAMS CIRCLE SUBDIVISION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1969 | 1969 WILLINGHAM DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 60.00 | 1 |  | Capacitor Bank | 2 | 134,400
1970 | 1970 WILLINGHAM DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 50.00 | 1 |  |  |  |
1971 | 1971 WILLINGHAM DRIVE | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1972 | 1972 WILLOW RUN ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1973 | 1973 WILLOW RUN ROAD | Distribution | Unattended | 115.00 | 25.00 |  | 25.00 | 1 |  |  |  |
1974 | 1974 WILMINGTON ISLAND | Transmission | Unattended | 115.00 | 13.80 |  | 80.00 | 2 |  |  |  |
1975 | 1975 WILMINGTON ISLAND | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 2 |  |  |  |
1976 | 1976 WILSON | Generation | Attended | 4.00 | 2.40 |  | 2.25 | 1 | 1 |  |  |
1977 | 1977 WILSON | Generation | Attended | 4.00 | 0.48 |  | 0.84 | 1 | 1 |  |  |
1978 | 1978 WILSON | Generation | Attended | 13.80 | 13.80 |  | 44.80 | 2 | 1 |  |  |
1979 | 1979 WILSON | Generation | Attended | 13.80 | 0.48 |  | 2.52 | 3 | 1 |  |  |
1980 | 1980 WILSON | Generation | Attended | 230.00 | 13.80 |  | 25.00 | 1 | 1 |  |  |
1981 | 1981 WILSON | Generation | Attended | 230.00 | 13.80 |  | 145.00 | 1 | 1 |  |  |
1982 | 1982 WILSON | Generation | Attended | 13.80 | 0.48 |  | 1.68 | 1 | 1 |  |  |
1983 | 1983 WILSON | Generation | Attended | 230.00 | 13.20 |  | 244.00 | 2 | 1 |  |  |
1984 | 1984 WINCHESTER SUBDIVISION PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
1985 | 1985 WIND GAP FARMS | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 3 |  |  |  |
1986 | 1986 WINDER PRIMARY | Distribution | Unattended | 115.00 | 25.00 |  | 40.00 | 1 |  | Capacitor Bank | 1 | 162,000
1987 | 1987 WINDER PRIMARY | Distribution | Unattended | 115.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1988 | 1988 WINDWARD | Distribution | Unattended | 230.00 | 12.00 |  | 40.00 | 1 |  |  |  |
1989 | 1989 WINDWARD | Distribution | Unattended | 230.00 | 25.00 |  | 180.00 | 3 |  |  |  |
1990 | 1990 WINDY HILL | Distribution | Unattended | 115.00 | 20.00 |  | 112.00 | 2 |  |  |  |
1991 | 1991 WINDY HILL | Distribution | Unattended | 20.00 | 12.00 |  | 22.40 | 1 |  |  |  |
1992 | 1992 WINN DIXIE PM (Powder Springs) | Distribution | Unattended | 46.00 | 12.00 |  | 0.75 | 3 |  |  |  |
1993 | 1993 WINN DIXIE (Atlanta) | Distribution | Unattended | 20.00 | 12.00 |  | 12.50 | 2 |  |  |  |
1994 | 1994 WINTERTHUR | Distribution | Unattended | 115.00 | 20.00 |  | 56.00 | 1 |  |  |  |
1995 | 1995 WINTERVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
1996 | 1996 WOODBINE | Distribution | Unattended | 115.00 | 12.00 |  | 14.00 | 2 |  |  |  |
1997 | 1997 WOODBURY | Distribution | Unattended | 46.00 | 12.00 |  | 7.00 | 1 |  |  |  |
1998 | 1998 WOODGRAIN MILLWORK | Distribution | Unattended | 46.00 | 4.00 |  | 4.69 | 1 |  |  |  |
1999 | 1999 WOODPECKER PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
2000 | 2000 WOODVALLEY | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
2001 | 2001 WRENS | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
2002 | 2002 WRENS | Distribution | Unattended | 46.00 | 12.00 |  | 4.20 | 1 |  |  |  |
2003 | 2003 WRENS | Distribution | Unattended | 46.00 | 12.00 |  | 5.25 | 1 |  |  |  |
2004 | 2004 WRENS AREA #1 PM | Distribution | Unattended | 46.00 | 12.00 |  | 0.25 | 1 |  |  |  |
2005 | 2005 WRENS PRIMARY | Distribution | Unattended | 46.00 | 25.00 |  | 8.13 | 1 |  |  |  |
2006 | 2006 WRENS PRIMARY | Distribution | Unattended | 230.00 | 46.00 |  | 60.00 | 1 |  |  |  |
2007 | 2007 WRIGHTSBORO ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
2008 | 2008 WRIGHTSVILLE | Distribution | Unattended | 46.00 | 12.00 |  | 8.40 | 2 |  |  |  |
2009 | 2009 WRIGHTSVILLE PRIMARY | Transmission | Unattended | 230.00 | 46.00 |  | 33.60 | 1 |  |  |  |
2010 | 2010 WYNNTON | Distribution | Unattended | 115.00 | 12.00 |  | 40.00 | 1 |  |  |  |
2011 | 2011 YAMAHA | Distribution | Unattended | 115.00 | 25.00 |  | 10.50 | 1 |  |  |  |
2012 | 2012 YAMAHA | Distribution | Unattended | 115.00 | 25.00 |  | 60.00 | 1 |  |  |  |
2013 | 2013 YATES 6&7 | Generation | Attended | 20.00 | 4.00 |  | 28.00 | 2 |  |  |  |
2014 | 2014 YATES 6&7 | Generation | Attended | 230.00 | 23.00 |  | 440.00 | 1 |  |  |  |
2015 | 2015 YATES 6&7 | Generation | Attended | 20.00 | 4.00 |  | 20.00 | 2 |  |  |  |
2016 | 2016 YATES 6&7 | Generation | Attended | 230.00 |  |  | 440.00 | 1 |  |  |  |
2017 | 2017 YATES COMMON | Transmission | Unattended | 115.00 | 46.00 |  | 50.00 | 1 |  | Capacitor Bank | 2 | 90,000
2018 | 2018 YATES VILLAGE PD | Distribution | Unattended | 46.00 | 12.00 |  | 2.50 | 1 |  |  |  |
2019 | 2019 YONAH | Generation | Attended | 115.00 | 12.00 |  | 10.50 | 1 |  |  |  |
2020 | 2020 YONAH | Generation | Attended | 115.00 | 6.60 |  | 30.00 | 3 |  |  |  |
2021 | 2021 YOSHIDA | Distribution | Unattended | 115.00 | 12.00 |  | 33.60 | 1 |  |  |  |
2022 | 2022 YOUNG STATION | Distribution | Unattended | 46.00 | 12.00 |  | 21.00 | 2 |  |  |  |
2023 | 2023 ZEBULON ROAD | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
2024 | 2024 ZIPPER | Distribution | Unattended | 115.00 | 12.00 |  | 25.00 | 1 |  |  |  |
1 | TotalDistributionSubstationMember |  |  |  |  |  | 43,112 |  |  |  |  | 5,741,069
2 | TotalGenerationSubstationMember |  |  |  |  |  | 33,026 |  |  |  |  | 561,600
3 | TotalTransmissionSubstationMember |  |  |  |  |  | 5,646 |  |  |  |  | 2,722,924
4 | Total |  |  |  |  |  | 81,784 |  |  |  |  | 9,025,593

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No. | Description of the Good or Service (a) | Name of Associated/Affiliated Company (b) | Account(s) Charged or Credited (c) | Amount Charged or Credited (d)
1 | Non-power Goods or Services Provided by Affiliated |  |  |
2 | Accounting, Finance, Treasury | (a) Southern Company Services | (c) See Notes | 42,761,587
3 | Administrative and General Services | Southern Company Services | (d) See Notes | 260,114,637
4 | Information Technology | Southern Company Services | (e) See Notes | 318,999,399
5 | Power Delivery Support Services | Southern Company Services | (f) See Notes | 234,689,822
6 | Nuclear Administrative and Other Related Services | (b) Southern Nuclear Operating Company | 182.3, 408.1,426.1,426.3, 426.4, 426.5, 524, 920, 921, 923, 926 | 95,677,712
7 | Nuclear Engineering Construction and Removal Serv. | Southern Nuclear Operating Company | 107, 108, 120.1, 184 | 387,565,516
8 | Nuclear Engineering Maintenance Services | Southern Nuclear Operating Company | 528-532 | 81,630,483
9 | Nuclear Engineering Operating Services | Southern Nuclear Operating Company | 143, 517-520, 523-525 | 333,339,660
10 | Other Power Generation | Southern Nuclear Operating Company | 546-549, 552-554 | 1,167,104
11 | Storm Assistance | Alabama Power Company | 107,108,182.3,184,593 | (g) 2,097,743
12 | Railcar Usage | Alabama Power Company | 151 | 673,281
13 | Material Sale | Alabama Power Company | 154 | 3,670,518
14 | Supplemental Executive Retirement Plan (SERP) | Alabama Power Company | 234 | 817,113
15 | Storm Assistance | Mississippi Power Company | 107,108,182.3,184,573,593 | (h) 1,360,476
16 | PPE Testing | Mississippi Power Company | 510, 511, 535, 542, 551, 552, 566,568, 588 | 644,039
19 |  |  |  |
20 | Non-power Goods or Services Provided for Affiliated |  |  |
21 | Administrative & Other Related Services | Southern Company Services | 146 | 15,667,412
22 | Material Services | Southern Company Services | 146 | 103,682
23 | Occupancy | Southern Company Services | 146 | 8,535,537
24 | Printing Service | Southern Company Services | 146 | 106,374
25 | Supply Chain Management | Southern Company Services | 146 | 4,920,984
26 | Vehicle Fleet Services | Southern Company Services | 146 | 343,039
27 | Material Sale | Alabama Power Company | 146 | 3,851,589
28 | Material Sale | Mississippi Power Company | 146 | (i) 663,930
42 |  |  |  |

Name of Respondent: Georgia Power Company | This report is: (1) ☑ An Original (2) ☐ A Resubmission | Date of Report: 04/01/2024 | Year/Period of Report End of: 2023 / Q4

FOOTNOTE DATA

(a) Concept: NameOfAssociatedAffiliatedCompany
Southern Company Services Southern Company Services, Inc. uses multiple allocation methodologies to allocate costs. These methodologies are designed to properly allocate cost on a causative basis and to prevent cross-subsidization among affiliated and non-affiliated companies. See Southern Company Services FERC Form 60 Schedule XXI for additional information. This note applies to Line Nos. 2, 3, 4, and 5 on page 429.
(b) Concept: NameOfAssociatedAffiliatedCompany
Southern Nuclear Operating Company Georgia Power Company (GPC) is billed direct and allocated costs by Southern Nuclear Operating Company Inc. (SNC). For the period of January through July 2023, SNC allocated costs to GPC using the Plant Basis Method. The Plant Basis Method of allocation is the factor determined by dividing one plant by total number of plants. GPC received 2/3 of SNC allocated costs since GPC owned two and Alabama Power Company (APC) owned one of the three plants operated by SNC during this period. Effective August 2023, SNC allocates costs to GPC using the Unit Basis Method. The Unit Basis Method of allocation is the factor determined by dividing one unit by the total number of units. GPC receives 3/5 of SNC allocated costs since GPC owns three and APC owns two of the five units operated by SNC. This note applies to Line Nos. 6, 7, 8, 9, and 10 on page 429.
(c) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Accounting, Finance & Treasury 174,416,501,506,547,561,562,568,901,903,905,921,923,928,930,421.1,421.2,408.2,426.5
(d) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Administrative and General Services 107,154,163,165,174,181,183,184,186,232,404,415,416,417,418,456,457,500,506,509,537,539,547, 549,555,557,560,561,562,566,568,569,570,571,573,580,581,582,584,586,587,588,590,592,593,594,596,597, 901,902,903,905,908,910,911,912,913,916,920,921,923,924,925,926,930,931,935,182.3,408.1,418.1,421.2, 426.4,408.2,426.1,426.5
(e) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Information Technology 107,108,184,232,403,506,524,553,566,586,587,588,590,597,902,903,908,912,921,923,930, 935,182.3,421.2
(f) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Power Delivery Support Services 107,108,165,183,184,186,404,412,416,431,500,501,502,505,506,510,511,512,513,514,517,519,520,524,525, 528,529,530,531,532,535,538,539,542,543,544,545,546,547,548,549,551,552,553,554,555,556,557,560,561, 562, 566,568,569,570,571,580,581,582,588,590,591,592,593,908,921,923,930,935,182.3,120.1,426.1,426.5
(g) Concept: DueToOrChargedByTheTransactionsWithAssociatedAffiliatedCompanies
APC is reporting $1,984,358 for Storm Assistance and GPC is reporting $2,097,743. The difference is due to timing.
(h) Concept: DueToOrChargedByTheTransactionsWithAssociatedAffiliatedCompanies
Mississippi Power Company is reporting $621,448 for PPE Testing and GPC is reporting $644,039. The difference is due to the timing of invoicing and payments.
(i) Concept: DueFromOrCreditedByTheTransactionsWithAssociatedAffiliatedCompanies