Document and Entity Information
Document and Entity Information | 9 Months Ended |
Sep. 30, 2018shares | |
Document Information [Line Items] | |
Entity Registrant Name | SOUTHERN CO |
Entity Central Index Key | 92,122 |
Document Type | 10-Q |
Document Period End Date | Sep. 30, 2018 |
Amendment Flag | false |
Document Fiscal Year Focus | 2,018 |
Document Fiscal Period Focus | Q3 |
Current Fiscal Year End Date | --12-31 |
Entity Filer Category | Large Accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 1,028,888,684 |
ALABAMA POWER CO | |
Document Information [Line Items] | |
Entity Registrant Name | ALABAMA POWER CO |
Entity Central Index Key | 3,153 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 30,537,500 |
GEORGIA POWER CO | |
Document Information [Line Items] | |
Entity Registrant Name | GEORGIA POWER CO |
Entity Central Index Key | 41,091 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 9,261,500 |
GULF POWER CO | |
Document Information [Line Items] | |
Entity Registrant Name | GULF POWER CO |
Entity Central Index Key | 44,545 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 7,392,717 |
MISSISSIPPI POWER CO | |
Document Information [Line Items] | |
Entity Registrant Name | MISSISSIPPI POWER CO |
Entity Central Index Key | 66,904 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 1,121,000 |
SOUTHERN POWER CO | |
Document Information [Line Items] | |
Entity Registrant Name | SOUTHERN POWER CO |
Entity Central Index Key | 1,160,661 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 1,000 |
SOUTHERN Co GAS | |
Document Information [Line Items] | |
Entity Registrant Name | SOUTHERN Co GAS |
Entity Central Index Key | 1,004,155 |
Entity Filer Category | Non-accelerated Filer |
Entity Emerging Growth Company | false |
Entity Small Business | false |
Entity Common Stock, Shares Outstanding | 100 |
Condensed Consolidated Statemen
Condensed Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Operating Revenues: | ||||
Total operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 |
Operating Expenses: | ||||
Other operations and maintenance | 1,404 | 1,341 | 4,217 | 4,100 |
Depreciation and amortization | 787 | 767 | 2,338 | 2,236 |
Taxes other than income taxes | 319 | 303 | 990 | 941 |
Estimated loss on plants under construction | 1 | 34 | 1,105 | 3,155 |
Gain on dispositions, net | (353) | 0 | (317) | (19) |
Impairment charges | 36 | 0 | 197 | 0 |
Goodwill impairment | 42 | |||
Total operating expenses | 3,985 | 4,210 | 14,545 | 15,809 |
Operating Income (Loss) | 2,174 | 1,991 | 3,613 | 1,594 |
Other Income and (Expense): | ||||
Allowance for equity funds used during construction | 36 | 18 | 99 | 133 |
Earnings from equity method investments | 36 | 32 | 108 | 100 |
Interest expense, net of amounts capitalized | (458) | (407) | (1,386) | (1,248) |
Other income (expense), net | 57 | 65 | 195 | 165 |
Total other income and (expense) | (329) | (292) | (984) | (850) |
Earnings (Loss) Before Income Taxes | 1,845 | 1,699 | 2,629 | 744 |
Income taxes | 623 | 590 | 598 | 317 |
Consolidated net income (loss) | 1,222 | 1,109 | 2,031 | 427 |
Dividends on preferred and preference stock of subsidiaries | 4 | 10 | 12 | 32 |
Net income attributable to noncontrolling interests | 54 | 30 | 71 | 48 |
Net Income (Loss) | $ 1,164 | $ 1,069 | $ 1,948 | $ 347 |
Earnings per share - | ||||
Basic (in dollars per share) | $ 1.14 | $ 1.07 | $ 1.92 | $ 0.35 |
Diluted (in dollars per share) | $ 1.13 | $ 1.06 | $ 1.91 | $ 0.35 |
Average number of shares of common stock outstanding (in millions) | ||||
Basic (in shares) | 1,023 | 1,003 | 1,016 | 998 |
Diluted (in shares) | 1,029 | 1,010 | 1,021 | 1,005 |
Cash dividends paid per share of common stock (in dollars per share) | $ 0.60 | $ 0.58 | $ 1.78 | $ 1.72 |
Retail electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | $ 4,605 | $ 4,615 | $ 11,913 | $ 11,786 |
Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 693 | 718 | 1,923 | 1,867 |
Other electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 170 | 168 | 509 | 510 |
Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 492 | 532 | 2,806 | 2,746 |
Operating Expenses: | ||||
Cost of goods and services sold | 104 | 134 | 1,053 | 1,085 |
Alternative revenue programs | ||||
Operating Revenues: | ||||
Total operating revenues | 5 | 0 | (23) | 9 |
Other | ||||
Operating Revenues: | ||||
Total operating revenues | 199 | 168 | 1,007 | 494 |
Operating Expenses: | ||||
Cost of goods and services sold | 120 | 90 | 688 | 293 |
Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 1,310 | 1,285 | 3,514 | 3,372 |
Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 257 | 256 | 760 | 646 |
ALABAMA POWER CO | ||||
Operating Revenues: | ||||
Total operating revenues | 1,740 | 1,740 | 4,716 | 4,606 |
Operating Expenses: | ||||
Other operations and maintenance | 401 | 406 | 1,191 | 1,177 |
Depreciation and amortization | 192 | 185 | 570 | 549 |
Taxes other than income taxes | 97 | 93 | 289 | 284 |
Total operating expenses | 1,179 | 1,139 | 3,403 | 3,203 |
Operating Income (Loss) | 561 | 601 | 1,313 | 1,403 |
Other Income and (Expense): | ||||
Allowance for equity funds used during construction | 16 | 11 | 43 | 27 |
Interest expense, net of amounts capitalized | (82) | (76) | (240) | (229) |
Other income (expense), net | 9 | 10 | 24 | 35 |
Total other income and (expense) | (57) | (55) | (173) | (167) |
Earnings (Loss) Before Income Taxes | 504 | 546 | 1,140 | 1,236 |
Income taxes | 127 | 216 | 272 | 493 |
Consolidated net income (loss) | 377 | 330 | 868 | 743 |
Dividends on preferred and preference stock of subsidiaries | 4 | 5 | 11 | 14 |
Net Income (Loss) | 373 | 325 | 857 | 729 |
ALABAMA POWER CO | Retail electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 1,584 | 1,595 | 4,208 | 4,155 |
ALABAMA POWER CO | Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 74 | 77 | 213 | 210 |
ALABAMA POWER CO | Wholesale revenues, affiliates | ||||
Operating Revenues: | ||||
Total operating revenues | 14 | 18 | 96 | 83 |
ALABAMA POWER CO | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 68 | 50 | 199 | 158 |
ALABAMA POWER CO | Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 356 | 343 | 1,028 | 944 |
ALABAMA POWER CO | Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 64 | 57 | 176 | 132 |
ALABAMA POWER CO | Purchased power, affiliates | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 69 | 55 | 149 | 117 |
GEORGIA POWER CO | ||||
Operating Revenues: | ||||
Total operating revenues | 2,593 | 2,546 | 6,601 | 6,426 |
Operating Expenses: | ||||
Other operations and maintenance | 460 | 430 | 1,325 | 1,248 |
Depreciation and amortization | 232 | 225 | 690 | 669 |
Taxes other than income taxes | 118 | 112 | 332 | 311 |
Estimated loss on plants under construction | 0 | 0 | 1,060 | 0 |
Total operating expenses | 1,602 | 1,529 | 5,569 | 4,305 |
Operating Income (Loss) | 991 | 1,017 | 1,032 | 2,121 |
Other Income and (Expense): | ||||
Allowance for equity funds used during construction | 50 | 29 | ||
Interest expense, net of amounts capitalized | (95) | (105) | (303) | (310) |
Other income (expense), net | 30 | 22 | 104 | 95 |
Total other income and (expense) | (65) | (83) | (199) | (215) |
Earnings (Loss) Before Income Taxes | 926 | 934 | 833 | 1,906 |
Income taxes | 262 | 350 | 212 | 705 |
Consolidated net income (loss) | 664 | 584 | 621 | 1,201 |
Dividends on preferred and preference stock of subsidiaries | 0 | 4 | 0 | 13 |
Net Income (Loss) | 664 | 580 | 621 | 1,188 |
GEORGIA POWER CO | Retail electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 2,425 | 2,402 | 6,112 | 5,995 |
GEORGIA POWER CO | Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 43 | 45 | 123 | 124 |
GEORGIA POWER CO | Wholesale revenues, affiliates | ||||
Operating Revenues: | ||||
Total operating revenues | 4 | 6 | 17 | 23 |
GEORGIA POWER CO | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 121 | 93 | 349 | 284 |
GEORGIA POWER CO | Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 480 | 482 | 1,269 | 1,297 |
GEORGIA POWER CO | Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 106 | 119 | 338 | 310 |
GEORGIA POWER CO | Purchased power, affiliates | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 206 | 161 | 555 | 470 |
GULF POWER CO | ||||
Operating Revenues: | ||||
Total operating revenues | 414 | 437 | 1,106 | 1,144 |
Operating Expenses: | ||||
Other operations and maintenance | 82 | 84 | 248 | 260 |
Depreciation and amortization | 48 | 42 | 142 | 95 |
Taxes other than income taxes | 33 | 33 | 91 | 88 |
Loss on Plant Scherer Unit 3 | 0 | 0 | 0 | 33 |
Total operating expenses | 339 | 324 | 921 | 915 |
Operating Income (Loss) | 75 | 113 | 185 | 229 |
Other Income and (Expense): | ||||
Interest expense, net of amounts capitalized | (13) | (13) | (39) | (37) |
Other income (expense), net | (3) | 3 | 0 | 7 |
Total other income and (expense) | (16) | (10) | (39) | (30) |
Earnings (Loss) Before Income Taxes | 59 | 103 | 146 | 199 |
Income taxes | (4) | 40 | (1) | 78 |
Consolidated net income (loss) | 63 | 63 | 147 | 121 |
Dividends on preferred and preference stock of subsidiaries | 0 | 0 | 0 | 4 |
Net Income (Loss) | 63 | 63 | 147 | 117 |
GULF POWER CO | Retail electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 341 | 375 | 932 | 972 |
GULF POWER CO | Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 15 | 14 | 41 | 44 |
GULF POWER CO | Wholesale revenues, affiliates | ||||
Operating Revenues: | ||||
Total operating revenues | 40 | 28 | 83 | 75 |
GULF POWER CO | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 18 | 20 | 50 | 53 |
GULF POWER CO | Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 132 | 127 | 305 | 323 |
GULF POWER CO | Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 44 | 38 | 135 | 116 |
MISSISSIPPI POWER CO | ||||
Operating Revenues: | ||||
Total operating revenues | 358 | 341 | 956 | 915 |
Operating Expenses: | ||||
Other operations and maintenance | 80 | 68 | 222 | 213 |
Depreciation and amortization | 42 | 39 | 126 | 120 |
Taxes other than income taxes | 28 | 25 | 83 | 77 |
Estimated loss on plants under construction | 1 | 34 | 45 | 3,155 |
Total operating expenses | 278 | 292 | 815 | 3,886 |
Operating Income (Loss) | 80 | 49 | 141 | (2,971) |
Other Income and (Expense): | ||||
Allowance for equity funds used during construction | 0 | 1 | 0 | 72 |
Interest expense, net of amounts capitalized | (19) | 13 | (59) | (23) |
Other income (expense), net | 0 | 1 | 28 | 4 |
Total other income and (expense) | (19) | 15 | (31) | 53 |
Earnings (Loss) Before Income Taxes | 61 | 64 | 110 | (2,918) |
Income taxes | 14 | 24 | 23 | (885) |
Consolidated net income (loss) | 47 | 40 | 87 | (2,033) |
Dividends on preferred and preference stock of subsidiaries | 0 | 0 | 1 | 1 |
Net Income (Loss) | 47 | 40 | 86 | (2,034) |
MISSISSIPPI POWER CO | Retail electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 254 | 243 | 660 | 665 |
MISSISSIPPI POWER CO | Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 65 | 72 | 184 | 196 |
MISSISSIPPI POWER CO | Wholesale revenues, affiliates | ||||
Operating Revenues: | ||||
Total operating revenues | 28 | 21 | 81 | 40 |
MISSISSIPPI POWER CO | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 11 | 5 | 31 | 14 |
MISSISSIPPI POWER CO | Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 116 | 120 | 312 | 301 |
MISSISSIPPI POWER CO | Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 11 | 6 | 27 | 20 |
SOUTHERN POWER CO | ||||
Operating Revenues: | ||||
Total operating revenues | 635 | 618 | 1,699 | 1,597 |
Operating Expenses: | ||||
Other operations and maintenance | 94 | 83 | 278 | 272 |
Depreciation and amortization | 130 | 131 | 370 | 379 |
Taxes other than income taxes | 12 | 13 | 36 | 37 |
Impairment charges | 36 | 0 | 155 | 0 |
Total operating expenses | 499 | 459 | 1,487 | 1,261 |
Operating Income (Loss) | 136 | 159 | 212 | 336 |
Other Income and (Expense): | ||||
Interest expense, net of amounts capitalized | (45) | (47) | (138) | (144) |
Other income (expense), net | 17 | 3 | 22 | 3 |
Total other income and (expense) | (28) | (44) | (116) | (141) |
Earnings (Loss) Before Income Taxes | 108 | 115 | 96 | 195 |
Income taxes | (38) | (39) | (210) | (129) |
Consolidated net income (loss) | 146 | 154 | 306 | 324 |
Net income attributable to noncontrolling interests | 54 | 30 | 71 | 48 |
Net Income (Loss) | 92 | 124 | 235 | 276 |
SOUTHERN POWER CO | Wholesale electric revenues | ||||
Operating Revenues: | ||||
Total operating revenues | 496 | 510 | 1,363 | 1,293 |
SOUTHERN POWER CO | Wholesale revenues, affiliates | ||||
Operating Revenues: | ||||
Total operating revenues | 134 | 105 | 326 | 295 |
SOUTHERN POWER CO | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 5 | 3 | 10 | 9 |
SOUTHERN POWER CO | Fuel | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 190 | 189 | 511 | 460 |
SOUTHERN POWER CO | Purchased power | ||||
Operating Expenses: | ||||
Cost of goods and services sold | 37 | 43 | 137 | 113 |
SOUTHERN Co GAS | ||||
Operating Revenues: | ||||
Total operating revenues | 492 | 565 | 2,861 | 2,841 |
Operating Expenses: | ||||
Other operations and maintenance | 216 | 206 | 730 | 675 |
Depreciation and amortization | 119 | 125 | 374 | 370 |
Taxes other than income taxes | 32 | 26 | 157 | 140 |
Gain on dispositions, net | (353) | 0 | (317) | 0 |
Goodwill impairment | 0 | 0 | 42 | 0 |
Total operating expenses | 118 | 498 | 2,051 | 2,290 |
Operating Income (Loss) | 374 | 67 | 810 | 551 |
Other Income and (Expense): | ||||
Earnings from equity method investments | 34 | 32 | 108 | 100 |
Interest expense, net of amounts capitalized | (52) | (51) | (170) | (145) |
Other income (expense), net | 6 | 19 | 21 | 30 |
Total other income and (expense) | (12) | 0 | (41) | (15) |
Earnings (Loss) Before Income Taxes | 362 | 67 | 769 | 536 |
Income taxes | 316 | 52 | 475 | 233 |
Consolidated net income (loss) | 46 | 15 | 294 | 303 |
Net Income (Loss) | 46 | 15 | 294 | 303 |
SOUTHERN Co GAS | Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 487 | 532 | 2,829 | 2,737 |
Operating Expenses: | ||||
Cost of goods and services sold | 104 | 134 | 1,053 | 1,085 |
SOUTHERN Co GAS | Alternative revenue programs | ||||
Operating Revenues: | ||||
Total operating revenues | 5 | 0 | (23) | 9 |
SOUTHERN Co GAS | Other | ||||
Operating Revenues: | ||||
Total operating revenues | 0 | 33 | 55 | 95 |
Operating Expenses: | ||||
Cost of goods and services sold | $ 0 | $ 7 | $ 12 | $ 20 |
Condensed Consolidated Statem_2
Condensed Consolidated Statements of Income (Unaudited) (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Total operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 |
Alternative revenue programs | ||||
Total operating revenues | 5 | 0 | (23) | 9 |
SOUTHERN Co GAS | ||||
Total operating revenues | 492 | 565 | 2,861 | 2,841 |
Excise taxes collected | 9 | 9 | 83 | 75 |
SOUTHERN Co GAS | Alternative revenue programs | ||||
Total operating revenues | $ 5 | $ 0 | $ (23) | $ 9 |
Condensed Consolidated Statem_3
Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Net income (loss) | $ 1,222 | $ 1,109 | $ 2,031 | $ 427 |
Qualifying hedges: | ||||
Changes in fair value, net of tax | (11) | 25 | (19) | 54 |
Reclassification adjustment for amounts included in net income, net of tax | 14 | (17) | 60 | (59) |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, net of tax | 8 | 1 | 11 | 3 |
Total other comprehensive income (loss) | 11 | 9 | 52 | (2) |
Comprehensive Income (Loss) | 1,233 | 1,118 | 2,083 | 425 |
Less: | ||||
Dividends on preferred and preference stock of subsidiaries | 4 | 10 | 12 | 32 |
Comprehensive income attributable to noncontrolling interests | 54 | 30 | 71 | 48 |
Comprehensive Income (Loss) Attributable to Parent | 1,175 | 1,078 | 2,000 | 345 |
ALABAMA POWER CO | ||||
Net income (loss) | 377 | 330 | 868 | 743 |
Qualifying hedges: | ||||
Reclassification adjustment for amounts included in net income, net of tax | 1 | 1 | 3 | 3 |
Pension and other postretirement benefit plans: | ||||
Total other comprehensive income (loss) | 1 | 1 | 3 | 3 |
Comprehensive Income (Loss) | 378 | 331 | 871 | 746 |
Less: | ||||
Dividends on preferred and preference stock of subsidiaries | 4 | 5 | 11 | 14 |
GEORGIA POWER CO | ||||
Net income (loss) | 664 | 584 | 621 | 1,201 |
Qualifying hedges: | ||||
Reclassification adjustment for amounts included in net income, net of tax | 1 | 1 | 3 | 2 |
Pension and other postretirement benefit plans: | ||||
Total other comprehensive income (loss) | 1 | 1 | 3 | 2 |
Comprehensive Income (Loss) | 665 | 585 | 624 | 1,203 |
Less: | ||||
Dividends on preferred and preference stock of subsidiaries | 0 | 4 | 0 | 13 |
GULF POWER CO | ||||
Net income (loss) | 63 | 63 | 147 | 121 |
Qualifying hedges: | ||||
Changes in fair value, net of tax | 0 | 0 | 0 | (1) |
Pension and other postretirement benefit plans: | ||||
Total other comprehensive income (loss) | 0 | 0 | 0 | (1) |
Comprehensive Income (Loss) | 63 | 63 | 147 | 120 |
Less: | ||||
Dividends on preferred and preference stock of subsidiaries | 0 | 0 | 0 | 4 |
MISSISSIPPI POWER CO | ||||
Net income (loss) | 47 | 40 | 87 | (2,033) |
Qualifying hedges: | ||||
Changes in fair value, net of tax | 0 | (1) | (1) | 0 |
Reclassification adjustment for amounts included in net income, net of tax | 0 | 0 | 1 | 1 |
Pension and other postretirement benefit plans: | ||||
Total other comprehensive income (loss) | 0 | (1) | 0 | 1 |
Comprehensive Income (Loss) | 47 | 39 | 87 | (2,032) |
Less: | ||||
Dividends on preferred and preference stock of subsidiaries | 0 | 0 | 1 | 1 |
SOUTHERN POWER CO | ||||
Net income (loss) | 146 | 154 | 306 | 324 |
Qualifying hedges: | ||||
Changes in fair value, net of tax | (11) | 25 | (19) | 58 |
Reclassification adjustment for amounts included in net income, net of tax | 11 | (20) | 46 | (68) |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, net of tax | 0 | 0 | 1 | 0 |
Total other comprehensive income (loss) | 0 | 5 | 28 | (10) |
Comprehensive Income (Loss) | 146 | 159 | 334 | 314 |
Less: | ||||
Comprehensive income attributable to noncontrolling interests | 54 | 30 | 71 | 48 |
Comprehensive Income (Loss) Attributable to Parent | 92 | 129 | 263 | 266 |
SOUTHERN Co GAS | ||||
Net income (loss) | 46 | 15 | 294 | 303 |
Qualifying hedges: | ||||
Changes in fair value, net of tax | 0 | 0 | 2 | (3) |
Reclassification adjustment for amounts included in net income, net of tax | 0 | 0 | 2 | 0 |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, net of tax | 6 | 0 | 5 | 0 |
Total other comprehensive income (loss) | 6 | 0 | 9 | (3) |
Comprehensive Income (Loss) | $ 52 | $ 15 | $ 303 | $ 300 |
Condensed Consolidated Statem_4
Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Qualifying hedges: | ||||
Changes in fair value, tax | $ (4) | $ 15 | $ (6) | $ 32 |
Reclassification adjustment for amounts included in net income, tax | 5 | (10) | 21 | (36) |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, tax | 3 | 1 | 4 | 2 |
ALABAMA POWER CO | ||||
Qualifying hedges: | ||||
Reclassification adjustment for amounts included in net income, tax | 0 | 1 | 1 | 2 |
GEORGIA POWER CO | ||||
Qualifying hedges: | ||||
Reclassification adjustment for amounts included in net income, tax | 0 | 0 | 1 | 1 |
GULF POWER CO | ||||
Qualifying hedges: | ||||
Changes in fair value, tax | 0 | 0 | 0 | (1) |
MISSISSIPPI POWER CO | ||||
Qualifying hedges: | ||||
Changes in fair value, tax | 0 | 0 | (1) | 0 |
Reclassification adjustment for amounts included in net income, tax | 0 | 0 | 0 | 0 |
SOUTHERN POWER CO | ||||
Qualifying hedges: | ||||
Changes in fair value, tax | (4) | 15 | (7) | 35 |
Reclassification adjustment for amounts included in net income, tax | 4 | (12) | 16 | (42) |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, tax | 0 | 0 | 0 | 0 |
SOUTHERN Co GAS | ||||
Qualifying hedges: | ||||
Changes in fair value, tax | 0 | 0 | 1 | (2) |
Reclassification adjustment for amounts included in net income, tax | 0 | 0 | 1 | 0 |
Pension and other postretirement benefit plans: | ||||
Reclassification adjustment for amounts included in net income, tax | $ 2 | $ 0 | $ 2 | $ (1) |
Condensed Consolidated Statem_5
Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2018 | Sep. 30, 2017 | |
Operating Activities: | ||
Net income (loss) | $ 2,031 | $ 427 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 2,647 | 2,564 |
Deferred income taxes | (286) | 15 |
Allowance for equity funds used during construction | (99) | (133) |
Pension, postretirement, and other employee benefits | (60) | (64) |
Settlement of asset retirement obligations | (160) | (137) |
Estimated loss on Plant Vogtle Units 3 and 4 | 1,105 | 3,155 |
Stock based compensation expense | 108 | 95 |
Estimated loss on plants under construction | 1,081 | 3,148 |
Gain on dispositions, net | (324) | (22) |
Impairment charges | 197 | 0 |
Gain on dispositions, net | (317) | (19) |
Goodwill impairment | 42 | |
Other, net | (21) | (80) |
Changes in certain current assets and liabilities — | ||
-Receivables | 37 | 423 |
-Prepayments | 14 | (39) |
-Natural gas for sale | 87 | 0 |
-Other current assets | (90) | (66) |
-Accounts payable | (248) | (467) |
-Accrued taxes | 839 | 157 |
-Accrued compensation | (138) | (230) |
-Retail fuel cost over recovery | 36 | (211) |
-Other current liabilities | (67) | (129) |
Net cash provided from operating activities | 5,584 | 5,251 |
Investing Activities: | ||
Business acquisitions, net of cash acquired | (64) | (1,016) |
Property additions | (5,793) | (5,242) |
Nuclear decommissioning trust fund purchases | (846) | (585) |
Nuclear decommissioning trust fund sales | 840 | 580 |
Asset dispositions | 2,773 | 66 |
Cost of removal, net of salvage | (252) | (208) |
Change in construction payables, net | 91 | 120 |
Investment in unconsolidated subsidiaries | (93) | (134) |
Payments pursuant to LTSAs | (157) | (189) |
Other investing activities | 1 | (77) |
Net cash provided from (used for) investing activities | (3,500) | (6,685) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | (1,225) | (515) |
Proceeds — | ||
Long-term debt | 1,950 | 4,068 |
Common stock | 878 | 613 |
Preferred stock | 0 | 250 |
Short-term borrowings | 3,150 | 1,263 |
Redemptions and repurchases — | ||
Long-term debt | (4,498) | (1,981) |
Preferred and preference stock | 0 | (150) |
Short-term borrowings | (1,800) | (409) |
Distributions to noncontrolling interests | (86) | (89) |
Capital contributions from noncontrolling interests | 1,333 | 79 |
Payment of common stock dividends | (1,805) | (1,716) |
Other financing activities | (237) | (113) |
Net cash provided from (used for) financing activities | (2,340) | 1,300 |
Net Change in Cash, Cash Equivalents, and Restricted Cash | (256) | (134) |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 2,147 | 1,992 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 1,891 | 1,858 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 1,402 | 1,286 |
Income taxes, net | 137 | (187) |
Noncash transactions — Accrued property additions at end of period | 1,125 | 805 |
ALABAMA POWER CO | ||
Operating Activities: | ||
Net income (loss) | 868 | 743 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 683 | 666 |
Deferred income taxes | 104 | 260 |
Allowance for equity funds used during construction | (43) | (27) |
Settlement of asset retirement obligations | (31) | (20) |
Other, net | (6) | 59 |
Changes in certain current assets and liabilities — | ||
-Receivables | (207) | (163) |
-Prepayments | (26) | (28) |
-Materials and supplies | (69) | (29) |
-Other current assets | 66 | 33 |
-Accounts payable | (194) | (125) |
-Accrued taxes | 225 | 159 |
-Accrued compensation | (41) | (48) |
-Retail fuel cost over recovery | 0 | (76) |
-Other current liabilities | 60 | 7 |
Net cash provided from operating activities | 1,389 | 1,411 |
Investing Activities: | ||
Property additions | (1,529) | (1,211) |
Nuclear decommissioning trust fund purchases | (207) | (174) |
Nuclear decommissioning trust fund sales | 207 | 174 |
Cost of removal, net of salvage | (78) | (82) |
Change in construction payables, net | 30 | 105 |
Other investing activities | (23) | (29) |
Net cash provided from (used for) investing activities | (1,600) | (1,217) |
Proceeds — | ||
Preferred stock | 0 | 250 |
Capital contributions from parent company | 495 | 337 |
Senior notes | 500 | 550 |
Redemptions and repurchases — | ||
Senior notes | 0 | (200) |
Pollution control revenue bonds | 0 | (36) |
Payment of common stock dividends | (602) | (536) |
Other financing activities | (24) | (26) |
Net cash provided from (used for) financing activities | 369 | 339 |
Net Change in Cash, Cash Equivalents, and Restricted Cash | 158 | 533 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 544 | 420 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 702 | 953 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 220 | 217 |
Income taxes, net | 30 | 146 |
Noncash transactions — Accrued property additions at end of period | 275 | 189 |
GEORGIA POWER CO | ||
Operating Activities: | ||
Net income (loss) | 621 | 1,201 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 854 | 821 |
Deferred income taxes | (185) | 328 |
Allowance for equity funds used during construction | (50) | (29) |
Pension, postretirement, and other employee benefits | (46) | (42) |
Settlement of asset retirement obligations | (82) | (95) |
Estimated loss on Plant Vogtle Units 3 and 4 | 1,060 | 0 |
Other, net | 9 | (51) |
Changes in certain current assets and liabilities — | ||
-Receivables | (205) | (254) |
-Fossil fuel stock | 70 | (2) |
-Prepaid income taxes | 231 | (5) |
-Other current assets | (36) | (24) |
-Accounts payable | 109 | (161) |
-Accrued taxes | 26 | (52) |
-Accrued compensation | (32) | (60) |
-Retail fuel cost over recovery | 0 | (84) |
-Other current liabilities | (111) | (11) |
Net cash provided from operating activities | 2,233 | 1,480 |
Investing Activities: | ||
Property additions | (2,276) | (1,907) |
Nuclear decommissioning trust fund purchases | (638) | (411) |
Nuclear decommissioning trust fund sales | 633 | 406 |
Asset dispositions | 138 | 63 |
Cost of removal, net of salvage | (71) | (54) |
Change in construction payables, net of joint owner portion | 72 | 180 |
Payments pursuant to LTSAs | (52) | (59) |
Other investing activities | (19) | (52) |
Net cash provided from (used for) investing activities | (2,213) | (1,834) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | 102 | (391) |
Proceeds — | ||
Short-term borrowings | 0 | 700 |
Capital contributions from parent company | 2,335 | 412 |
Senior notes | 0 | 1,350 |
Other long-term debt | 0 | 370 |
Redemptions and repurchases — | ||
Senior notes | (1,000) | (450) |
Pollution control revenue bonds | (469) | (65) |
Other long-term debt | (100) | 0 |
Short-term borrowings | (150) | (300) |
Payment of common stock dividends | (1,043) | (961) |
Premiums on redemption and repurchases of senior notes | (152) | 0 |
Other financing activities | (15) | (48) |
Net cash provided from (used for) financing activities | (492) | 617 |
Net Change in Cash, Cash Equivalents, and Restricted Cash | (472) | 263 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 852 | 3 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 380 | 266 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 315 | 284 |
Income taxes, net | 141 | 369 |
Noncash transactions — Accrued property additions at end of period | 670 | 470 |
GULF POWER CO | ||
Operating Activities: | ||
Net income (loss) | 147 | 121 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 147 | 100 |
Deferred income taxes | (45) | 57 |
Loss on Plant Scherer Unit 3 | 0 | 33 |
Other, net | (10) | (5) |
Changes in certain current assets and liabilities — | ||
-Receivables | (5) | (65) |
-Other current assets | 9 | 18 |
-Accrued taxes | 35 | 21 |
-Accrued compensation | (9) | (10) |
-Over recovered regulatory clause revenues | 39 | (8) |
-Other current liabilities | 10 | 10 |
Net cash provided from operating activities | 318 | 272 |
Investing Activities: | ||
Property additions | (207) | (142) |
Cost of removal, net of salvage | (18) | (16) |
Change in construction payables, net | 5 | (9) |
Other investing activities | (18) | (6) |
Net cash provided from (used for) investing activities | (238) | (173) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | 5 | (268) |
Proceeds — | ||
Common stock | 0 | 175 |
Capital contributions from parent company | 40 | 7 |
Senior notes | 0 | 300 |
Redemptions and repurchases — | ||
Preferred and preference stock | 0 | (150) |
Senior notes | 0 | (85) |
Payment of common stock dividends | (115) | (94) |
Other financing activities | (1) | (3) |
Net cash provided from (used for) financing activities | (71) | (118) |
Net Change in Cash, Cash Equivalents, and Restricted Cash | 9 | (19) |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 28 | 56 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 37 | 37 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 26 | 24 |
Income taxes, net | 28 | 19 |
Noncash transactions — Accrued property additions at end of period | 31 | 25 |
MISSISSIPPI POWER CO | ||
Operating Activities: | ||
Net income (loss) | 87 | (2,033) |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 129 | 144 |
Deferred income taxes | 420 | (1,159) |
Allowance for equity funds used during construction | 0 | (72) |
Estimated loss on Plant Vogtle Units 3 and 4 | 45 | 3,155 |
Estimated loss on plants under construction | 21 | 3,148 |
Other, net | 5 | (26) |
Changes in certain current assets and liabilities — | ||
-Receivables | (46) | 438 |
-Fossil fuel stock | (2) | 21 |
-Other current assets | (5) | (9) |
-Accounts payable | (3) | (21) |
-Accrued taxes | 57 | 20 |
-Accrued compensation | (9) | (12) |
-Over recovered regulatory clause revenues | 20 | (47) |
-Other current liabilities | (18) | (31) |
Net cash provided from operating activities | 656 | 361 |
Investing Activities: | ||
Property additions | (117) | (411) |
Change in construction payables, net | (9) | (47) |
Payments pursuant to LTSAs | (28) | (10) |
Other investing activities | (16) | (15) |
Net cash provided from (used for) investing activities | (170) | (483) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | (4) | (23) |
Proceeds — | ||
Short-term borrowings | 300 | 113 |
Capital contributions from parent company | (2) | 1,002 |
Senior notes | 600 | 0 |
Long-term debt to parent company | 0 | 40 |
Redemptions and repurchases — | ||
Pollution control revenue bonds | (43) | 0 |
Other long-term debt | (900) | (300) |
Short-term borrowings | (300) | (109) |
Long-term debt to parent company | 0 | (591) |
Other financing activities | (6) | (3) |
Net cash provided from (used for) financing activities | (355) | 129 |
Net Change in Cash, Cash Equivalents, and Restricted Cash | 131 | 7 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 248 | 224 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 379 | 231 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 57 | 45 |
Income taxes, net | (483) | (209) |
Noncash transactions — Accrued property additions at end of period | 23 | 32 |
SOUTHERN POWER CO | ||
Operating Activities: | ||
Net income (loss) | 306 | 324 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 394 | 404 |
Deferred income taxes | (337) | 240 |
Amortization of investment tax credits | (43) | (42) |
Income taxes receivable, non-current | (12) | (42) |
Impairment charges | 155 | 0 |
Other, net | 10 | (4) |
Changes in certain current assets and liabilities — | ||
-Receivables | (41) | (77) |
-Prepaid income taxes | 5 | 24 |
-Other current assets | 1 | 14 |
-Accounts payable | (27) | (31) |
-Accrued taxes | 256 | 79 |
-Other current liabilities | (1) | 5 |
Net cash provided from operating activities | 666 | 894 |
Investing Activities: | ||
Business acquisitions, net of cash acquired | (64) | (1,016) |
Property additions | (226) | (218) |
Change in construction payables, net | 3 | (166) |
Payments pursuant to LTSAs | (57) | (99) |
Other investing activities | 20 | 7 |
Net cash provided from (used for) investing activities | (324) | (1,492) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | (68) | (89) |
Proceeds — | ||
Short-term borrowings | 200 | 0 |
Other long-term debt | 0 | 43 |
Redemptions and repurchases — | ||
Senior notes | (350) | 0 |
Other long-term debt | (420) | (4) |
Return of capital | (650) | 0 |
Distributions to noncontrolling interests | (86) | (89) |
Capital contributions from noncontrolling interests | 1,333 | 79 |
Payment of common stock dividends | (234) | (238) |
Other financing activities | (15) | (27) |
Net cash provided from (used for) financing activities | (290) | (325) |
Net Change in Cash, Cash Equivalents, and Restricted Cash | 52 | (923) |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 140 | 1,112 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 192 | 189 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 138 | 144 |
Income taxes, net | (102) | (343) |
Noncash transactions — Accrued property additions at end of period | 37 | 16 |
SOUTHERN Co GAS | ||
Operating Activities: | ||
Net income (loss) | 294 | 303 |
Adjustments to reconcile net income (loss) to net cash provided from operating activities — | ||
Depreciation and amortization, total | 374 | 370 |
Deferred income taxes | (83) | 265 |
Mark-to-market adjustments | 23 | (32) |
Gain on dispositions, net | (317) | 0 |
Goodwill impairment | 42 | 0 |
Other, net | (41) | (46) |
Changes in certain current assets and liabilities — | ||
-Receivables | 445 | 531 |
-Natural gas for sale | 87 | 0 |
-Prepaid income taxes | (23) | (7) |
-Other current assets | 21 | (42) |
-Accounts payable | (59) | (169) |
-Accrued taxes | (64) | (24) |
-Accrued compensation | 2 | (11) |
-Other current liabilities | 35 | 8 |
Net cash provided from operating activities | 736 | 1,146 |
Investing Activities: | ||
Property additions | (1,029) | (1,093) |
Asset dispositions | 2,631 | 0 |
Cost of removal, net of salvage | (67) | (45) |
Change in construction payables, net | (14) | 49 |
Investment in unconsolidated subsidiaries | (90) | (128) |
Other investing activities | 18 | 28 |
Net cash provided from (used for) investing activities | 1,449 | (1,189) |
Financing Activities: | ||
Increase (decrease) in notes payable, net | (1,382) | (323) |
Proceeds — | ||
First mortgage bonds | 100 | 200 |
Capital contributions from parent company | 35 | 79 |
Senior notes | 0 | 450 |
Redemptions and repurchases — | ||
Long-term debt | (200) | 0 |
Return of capital | (400) | 0 |
Payment of common stock dividends | (351) | (332) |
Other financing activities | (3) | (29) |
Net cash provided from (used for) financing activities | (2,201) | 45 |
Net Change in Cash, Cash Equivalents, and Restricted Cash | (16) | 2 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 78 | 24 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 62 | 26 |
Cash paid (received) during the period for — | ||
Interest, net of amounts capitalized | 175 | 146 |
Income taxes, net | 682 | 17 |
Noncash transactions — Accrued property additions at end of period | $ 121 | $ 112 |
Condensed Consolidated Statem_6
Condensed Consolidated Statements of Cash Flows (Unaudited) (Parenthetical) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2018 | Sep. 30, 2017 | |
Interest capitalized | $ 53 | $ 72 |
ALABAMA POWER CO | ||
Interest capitalized | 15 | 10 |
GEORGIA POWER CO | ||
Interest capitalized | 19 | 17 |
GULF POWER CO | ||
Interest capitalized | 0 | 0 |
MISSISSIPPI POWER CO | ||
Interest paid | 57 | 73 |
Interest capitalized | 0 | 28 |
SOUTHERN POWER CO | ||
Interest capitalized | 14 | 7 |
SOUTHERN Co GAS | ||
Interest capitalized | $ 5 | $ 9 |
Condensed Consolidated Balance
Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Current Assets: | ||
Cash and cash equivalents | $ 1,847 | $ 2,130 |
Receivables — | ||
Customer accounts receivable | 1,730 | 1,806 |
Energy marketing receivables | 498 | 607 |
Unbilled revenues | 738 | 810 |
Under recovered fuel clause revenues | 105 | 171 |
Other accounts and notes receivable | 690 | 698 |
Accumulated provision for uncollectible accounts | (33) | (44) |
Materials and supplies | 1,418 | 1,438 |
Fossil fuel for generation | 390 | 594 |
Natural gas for sale | 486 | 595 |
Prepaid expenses | 354 | 452 |
Other regulatory assets, current | 522 | 604 |
Assets held for sale, current | 407 | 12 |
Other current assets | 232 | 199 |
Total current assets | 9,384 | 10,072 |
Property, Plant, and Equipment: | ||
In service | 100,672 | 103,542 |
Less: Accumulated depreciation | 30,739 | 31,457 |
Plant in service, net of depreciation | 69,933 | 72,085 |
Nuclear fuel, at amortized cost | 844 | 883 |
Construction work in progress | 7,655 | 6,904 |
Total property, plant, and equipment | 78,432 | 79,872 |
Other Property and Investments: | ||
Goodwill | 5,315 | 6,268 |
Equity investments in unconsolidated subsidiaries | 1,569 | 1,513 |
Other intangible assets, net of amortization | 674 | 873 |
Nuclear decommissioning trusts, at fair value | 1,872 | 1,832 |
Leveraged leases | 794 | 775 |
Miscellaneous property and investments | 258 | 249 |
Total other property and investments | 10,482 | 11,510 |
Deferred Charges and Other Assets: | ||
Deferred charges related to income taxes | 792 | 825 |
Unamortized loss on reacquired debt | 328 | 206 |
Other regulatory assets, deferred | 6,196 | 6,943 |
Assets held for sale | 4,667 | 0 |
Other deferred charges and assets | 1,436 | 1,577 |
Total deferred charges and other assets | 13,419 | 9,551 |
Total Assets | 111,717 | 111,005 |
Current Liabilities: | ||
Securities due within one year | 3,013 | 3,892 |
Notes payable | 2,564 | 2,439 |
Energy marketing trade payables | 521 | 546 |
Accounts payable — | ||
Accounts payable | 2,246 | 2,530 |
Customer deposits | 524 | 542 |
Accrued taxes — | ||
Accrued taxes | 1,060 | 636 |
Accrued interest | 422 | 488 |
Accrued compensation | 800 | 959 |
Asset retirement obligations, current | 348 | 351 |
Other regulatory liabilities, current | 349 | 337 |
Liabilities held for sale, current | 355 | 0 |
Other current liabilities | 763 | 874 |
Total current liabilities | 12,965 | 13,594 |
Long-term Debt | 41,425 | 44,462 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 6,035 | 6,842 |
Deferred credits related to income taxes | 6,651 | 7,256 |
Accumulated deferred ITCs | 2,377 | 2,267 |
Employee benefit obligations | 2,017 | 2,256 |
Asset retirement obligations, deferred | 5,817 | 4,473 |
Accrued environmental remediation | 269 | 389 |
Other cost of removal obligations | 2,330 | 2,684 |
Other regulatory liabilities, deferred | 153 | 239 |
Liabilities held for sale | 2,835 | 0 |
Other deferred credits and liabilities | 454 | 691 |
Total deferred credits and other liabilities | 28,938 | 27,097 |
Total Liabilities | 83,328 | 85,153 |
Redeemable Preferred Stock of Subsidiaries | 324 | 324 |
Common Stockholders' Equity: | ||
Common stock | 5,140 | 5,038 |
Paid-in capital | 10,905 | 10,469 |
Treasury, at cost | (39) | (36) |
Retained earnings (accumulated deficit) | 9,048 | 8,885 |
Accumulated other comprehensive income (loss) | (177) | (189) |
Total Common Stockholders' Equity | 24,877 | 24,167 |
Noncontrolling interests | 3,188 | 1,361 |
Total stockholders' equity | 28,065 | 25,528 |
Total Liabilities and Stockholders' Equity | 111,717 | 111,005 |
ALABAMA POWER CO | ||
Current Assets: | ||
Cash and cash equivalents | 702 | 544 |
Receivables — | ||
Customer accounts receivable | 455 | 355 |
Unbilled revenues | 159 | 162 |
Under recovered fuel clause revenues | 48 | 0 |
Affiliated | 68 | 43 |
Other accounts and notes receivable | 54 | 55 |
Accumulated provision for uncollectible accounts | (9) | (9) |
Materials and supplies | 536 | 458 |
Fossil fuel for generation | 117 | 184 |
Prepaid expenses | 59 | 85 |
Other regulatory assets, current | 141 | 124 |
Other current assets | 8 | 5 |
Total current assets | 2,338 | 2,006 |
Property, Plant, and Equipment: | ||
In service | 29,568 | 27,326 |
Less: Accumulated depreciation | 9,932 | 9,563 |
Plant in service, net of depreciation | 19,636 | 17,763 |
Nuclear fuel, at amortized cost | 316 | 339 |
Construction work in progress | 1,457 | 908 |
Total property, plant, and equipment | 21,409 | 19,010 |
Other Property and Investments: | ||
Equity investments in unconsolidated subsidiaries | 63 | 67 |
Nuclear decommissioning trusts, at fair value | 938 | 903 |
Miscellaneous property and investments | 127 | 124 |
Total other property and investments | 1,128 | 1,094 |
Deferred Charges and Other Assets: | ||
Deferred charges related to income taxes | 236 | 239 |
Deferred under recovered regulatory clause revenues | 88 | 54 |
Other regulatory assets, deferred | 1,209 | 1,272 |
Other deferred charges and assets | 202 | 189 |
Total deferred charges and other assets | 1,735 | 1,754 |
Total Assets | 26,610 | 23,864 |
Current Liabilities: | ||
Securities due within one year | 321 | 0 |
Accounts payable — | ||
Affiliated | 341 | 327 |
Other | 425 | 585 |
Customer deposits | 96 | 92 |
Accrued taxes — | ||
Accrued income taxes | 97 | 9 |
Other accrued taxes | 132 | 45 |
Accrued interest | 81 | 77 |
Accrued compensation | 169 | 205 |
Asset retirement obligations, current | 111 | 7 |
Other regulatory liabilities, current | 57 | 1 |
Other current liabilities | 46 | 52 |
Total current liabilities | 1,876 | 1,400 |
Long-term Debt | 7,803 | 7,628 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 2,882 | 2,760 |
Deferred credits related to income taxes | 2,051 | 2,082 |
Accumulated deferred ITCs | 107 | 112 |
Employee benefit obligations | 283 | 304 |
Asset retirement obligations, deferred | 3,090 | 1,702 |
Other cost of removal obligations | 542 | 609 |
Other regulatory liabilities, deferred | 52 | 84 |
Other deferred credits and liabilities | 48 | 63 |
Total deferred credits and other liabilities | 9,055 | 7,716 |
Total Liabilities | 18,734 | 16,744 |
Redeemable Preferred Stock | 291 | 291 |
Common Stockholders' Equity: | ||
Common stock | 1,222 | 1,222 |
Paid-in capital | 3,490 | 2,986 |
Retained earnings (accumulated deficit) | 2,902 | 2,647 |
Accumulated other comprehensive income (loss) | (29) | (26) |
Total Common Stockholders' Equity | 7,585 | 6,829 |
Total Liabilities and Stockholders' Equity | 26,610 | 23,864 |
GEORGIA POWER CO | ||
Current Assets: | ||
Cash and cash equivalents | 380 | 852 |
Receivables — | ||
Customer accounts receivable | 747 | 544 |
Unbilled revenues | 245 | 255 |
Under recovered fuel clause revenues | 105 | 165 |
Joint owner accounts receivable | 208 | 262 |
Affiliated | 39 | 24 |
Other accounts and notes receivable | 96 | 76 |
Accumulated provision for uncollectible accounts | (3) | (3) |
Materials and supplies | 494 | 504 |
Fossil fuel for generation | 244 | 314 |
Prepaid expenses | 77 | 216 |
Other regulatory assets, current | 199 | 205 |
Other current assets | 91 | 14 |
Total current assets | 2,922 | 3,428 |
Property, Plant, and Equipment: | ||
In service | 35,671 | 34,861 |
Less: Accumulated depreciation | 12,029 | 11,704 |
Plant in service, net of depreciation | 23,642 | 23,157 |
Nuclear fuel, at amortized cost | 528 | 544 |
Construction work in progress | 4,655 | 4,613 |
Total property, plant, and equipment | 28,825 | 28,314 |
Other Property and Investments: | ||
Equity investments in unconsolidated subsidiaries | 50 | 53 |
Nuclear decommissioning trusts, at fair value | 933 | 929 |
Miscellaneous property and investments | 61 | 59 |
Total other property and investments | 1,044 | 1,041 |
Deferred Charges and Other Assets: | ||
Deferred charges related to income taxes | 519 | 516 |
Other regulatory assets, deferred | 3,041 | 2,932 |
Other deferred charges and assets | 510 | 548 |
Total deferred charges and other assets | 4,070 | 3,996 |
Total Assets | 36,861 | 36,779 |
Current Liabilities: | ||
Securities due within one year | 511 | 857 |
Notes payable | 102 | 150 |
Accounts payable — | ||
Affiliated | 515 | 493 |
Other | 909 | 834 |
Customer deposits | 275 | 270 |
Accrued taxes — | ||
Accrued taxes | 345 | 344 |
Accrued interest | 108 | 123 |
Accrued compensation | 185 | 219 |
Asset retirement obligations, current | 193 | 270 |
Other regulatory liabilities, current | 151 | 191 |
Other current liabilities | 180 | 198 |
Total current liabilities | 3,474 | 3,949 |
Long-term Debt | 9,863 | 11,073 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 2,999 | 3,175 |
Deferred credits related to income taxes | 3,218 | 3,248 |
Accumulated deferred ITCs | 264 | 248 |
Employee benefit obligations | 650 | 659 |
Asset retirement obligations, deferred | 2,401 | 2,368 |
Other deferred credits and liabilities | 141 | 128 |
Total deferred credits and other liabilities | 9,673 | 9,826 |
Total Liabilities | 23,010 | 24,848 |
Common Stockholders' Equity: | ||
Common stock | 398 | 398 |
Paid-in capital | 9,670 | 7,328 |
Retained earnings (accumulated deficit) | 3,792 | 4,215 |
Accumulated other comprehensive income (loss) | (9) | (10) |
Total Common Stockholders' Equity | 13,851 | 11,931 |
Total Liabilities and Stockholders' Equity | 36,861 | 36,779 |
GULF POWER CO | ||
Current Assets: | ||
Cash and cash equivalents | 37 | 28 |
Receivables — | ||
Customer accounts receivable | 100 | 76 |
Unbilled revenues | 69 | 67 |
Under recovered fuel clause revenues | 0 | 27 |
Affiliated | 20 | 14 |
Other accounts and notes receivable | 5 | 7 |
Accumulated provision for uncollectible accounts | (1) | (1) |
Materials and supplies | 61 | 57 |
Fossil fuel for generation | 58 | 63 |
Other regulatory assets, current | 47 | 56 |
Other current assets | 13 | 21 |
Total current assets | 409 | 415 |
Property, Plant, and Equipment: | ||
In service | 5,313 | 5,196 |
Less: Accumulated depreciation | 1,540 | 1,461 |
Plant in service, net of depreciation | 3,773 | 3,735 |
Construction work in progress | 152 | 91 |
Total property, plant, and equipment | 3,925 | 3,826 |
Deferred Charges and Other Assets: | ||
Deferred charges related to income taxes | 30 | 31 |
Other regulatory assets, deferred | 495 | 502 |
Other deferred charges and assets | 46 | 23 |
Total deferred charges and other assets | 571 | 556 |
Total Assets | 4,905 | 4,797 |
Current Liabilities: | ||
Notes payable | 50 | 45 |
Accounts payable — | ||
Affiliated | 64 | 52 |
Other | 67 | 75 |
Customer deposits | 35 | 35 |
Accrued taxes — | ||
Accrued taxes | 45 | 10 |
Accrued interest | 20 | 9 |
Accrued compensation | 30 | 39 |
Deferred capacity expense, current | 22 | 22 |
Asset retirement obligations, current | 43 | 37 |
Other regulatory liabilities, current | 69 | 0 |
Other current liabilities | 20 | 27 |
Total current liabilities | 465 | 351 |
Long-term Debt | 1,285 | 1,285 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 542 | 537 |
Deferred credits related to income taxes | 380 | 458 |
Employee benefit obligations | 96 | 102 |
Deferred capacity expense | 81 | 97 |
Asset retirement obligations, deferred | 121 | 105 |
Other cost of removal obligations | 218 | 221 |
Other regulatory liabilities, deferred | 51 | 43 |
Other deferred credits and liabilities | 62 | 67 |
Total deferred credits and other liabilities | 1,551 | 1,630 |
Total Liabilities | 3,301 | 3,266 |
Common Stockholders' Equity: | ||
Common stock | 678 | 678 |
Paid-in capital | 636 | 594 |
Retained earnings (accumulated deficit) | 291 | 259 |
Accumulated other comprehensive income (loss) | (1) | 0 |
Total Common Stockholders' Equity | 1,604 | 1,531 |
Total Liabilities and Stockholders' Equity | 4,905 | 4,797 |
MISSISSIPPI POWER CO | ||
Current Assets: | ||
Cash and cash equivalents | 379 | 248 |
Receivables — | ||
Customer accounts receivable | 49 | 36 |
Unbilled revenues | 43 | 41 |
Income taxes receivable, current | 3 | 4 |
Affiliated | 35 | 16 |
Other accounts and notes receivable | 47 | 12 |
Materials and supplies | 52 | 44 |
Fossil fuel for generation | 19 | 17 |
Other regulatory assets, current | 110 | 125 |
Other current assets | 4 | 9 |
Total current assets | 741 | 552 |
Property, Plant, and Equipment: | ||
In service | 4,819 | 4,773 |
Less: Accumulated depreciation | 1,389 | 1,325 |
Plant in service, net of depreciation | 3,430 | 3,448 |
Construction work in progress | 106 | 84 |
Total property, plant, and equipment | 3,536 | 3,532 |
Other Property and Investments: | ||
Total other property and investments | 24 | 30 |
Deferred Charges and Other Assets: | ||
Deferred charges related to income taxes | 34 | 35 |
Other regulatory assets, deferred | 466 | 437 |
Accumulated deferred income taxes | 0 | 247 |
Other deferred charges and assets | 16 | 33 |
Total deferred charges and other assets | 516 | 752 |
Total Assets | 4,817 | 4,866 |
Current Liabilities: | ||
Securities due within one year | 204 | 989 |
Notes payable | 0 | 4 |
Accounts payable — | ||
Affiliated | 55 | 59 |
Other | 90 | 96 |
Accrued taxes — | ||
Accrued income taxes | 75 | 40 |
Other accrued taxes | 74 | 101 |
Accrued interest | 21 | 16 |
Accrued compensation | 30 | 39 |
Accrued plant closure costs | 30 | 35 |
Asset retirement obligations, current | 41 | 37 |
Other current liabilities | 56 | 47 |
Total current liabilities | 676 | 1,463 |
Long-term Debt | 1,532 | 1,097 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 193 | 0 |
Deferred credits related to income taxes | 420 | 372 |
Employee benefit obligations | 111 | 116 |
Asset retirement obligations, deferred | 136 | 137 |
Other cost of removal obligations | 181 | 178 |
Other regulatory liabilities, deferred | 75 | 79 |
Other deferred credits and liabilities | 17 | 33 |
Total deferred credits and other liabilities | 1,133 | 915 |
Total Liabilities | 3,341 | 3,475 |
Redeemable Preferred Stock | 33 | 33 |
Common Stockholders' Equity: | ||
Common stock | 38 | 38 |
Paid-in capital | 4,528 | 4,529 |
Retained earnings (accumulated deficit) | (3,119) | (3,205) |
Accumulated other comprehensive income (loss) | (4) | (4) |
Total Common Stockholders' Equity | 1,443 | 1,358 |
Total Liabilities and Stockholders' Equity | 4,817 | 4,866 |
SOUTHERN POWER CO | ||
Current Assets: | ||
Cash and cash equivalents | 192 | 129 |
Receivables — | ||
Customer accounts receivable | 150 | 117 |
Affiliated | 71 | 50 |
Other accounts and notes receivable | 62 | 98 |
Materials and supplies | 214 | 278 |
Prepaid income taxes | 44 | 50 |
Assets held for sale, current | 18 | 1 |
Other current assets | 29 | 35 |
Total current assets | 780 | 758 |
Property, Plant, and Equipment: | ||
In service | 13,603 | 13,755 |
Less: Accumulated depreciation | 2,087 | 1,910 |
Plant in service, net of depreciation | 11,516 | 11,845 |
Construction work in progress | 586 | 511 |
Total property, plant, and equipment | 12,102 | 12,356 |
Other Property and Investments: | ||
Intangible assets, net of amortization | 391 | 411 |
Total other property and investments | 391 | 411 |
Deferred Charges and Other Assets: | ||
Prepaid LTSAs | 106 | 118 |
Accumulated deferred income taxes | 1,281 | 925 |
Income taxes receivable, non-current | 84 | 72 |
Assets held for sale | 185 | 0 |
Other deferred charges and assets | 426 | 566 |
Total deferred charges and other assets | 2,082 | 1,681 |
Total Assets | 15,355 | 15,206 |
Current Liabilities: | ||
Securities due within one year | 0 | 770 |
Notes payable | 237 | 105 |
Accounts payable — | ||
Affiliated | 86 | 102 |
Other | 88 | 103 |
Accrued taxes — | ||
Accrued income taxes | 233 | 0 |
Liabilities held for sale, current | 4 | 0 |
Other current liabilities | 165 | 152 |
Total current liabilities | 813 | 1,232 |
Long-term Debt | 5,029 | 5,071 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 111 | 199 |
Accumulated deferred ITCs | 1,842 | 1,884 |
Other deferred credits and liabilities | 259 | 322 |
Total deferred credits and other liabilities | 2,212 | 2,405 |
Total Liabilities | 8,054 | 8,708 |
Common Stockholders' Equity: | ||
Common stock | 0 | 0 |
Paid-in capital | 2,604 | 3,662 |
Retained earnings (accumulated deficit) | 1,478 | 1,478 |
Accumulated other comprehensive income (loss) | 31 | (2) |
Total Common Stockholders' Equity | 4,113 | 5,138 |
Noncontrolling interests | 3,188 | 1,360 |
Total stockholders' equity | 7,301 | 6,498 |
Total Liabilities and Stockholders' Equity | 15,355 | 15,206 |
SOUTHERN Co GAS | ||
Current Assets: | ||
Cash and cash equivalents | 56 | 73 |
Receivables — | ||
Customer accounts receivable | 180 | 400 |
Energy marketing receivables | 498 | 607 |
Unbilled revenues | 58 | 285 |
Affiliated | 23 | 12 |
Other accounts and notes receivable | 110 | 91 |
Accumulated provision for uncollectible accounts | (18) | (28) |
Natural gas for sale | 486 | 595 |
Prepaid expenses | 62 | 53 |
Assets from risk management activities, net of collateral | 87 | 135 |
Other regulatory assets, current | 72 | 94 |
Other current assets | 88 | 78 |
Total current assets | 1,702 | 2,395 |
Property, Plant, and Equipment: | ||
In service | 14,771 | 15,833 |
Less: Accumulated depreciation | 4,351 | 4,596 |
Plant in service, net of depreciation | 10,420 | 11,237 |
Construction work in progress | 660 | 491 |
Total property, plant, and equipment | 11,080 | 11,728 |
Other Property and Investments: | ||
Goodwill | 5,015 | 5,967 |
Equity investments in unconsolidated subsidiaries | 1,529 | 1,477 |
Other intangible assets, net of amortization | 113 | 280 |
Miscellaneous property and investments | 20 | 21 |
Total other property and investments | 6,677 | 7,745 |
Deferred Charges and Other Assets: | ||
Other regulatory assets, deferred | 721 | 901 |
Other deferred charges and assets | 218 | 218 |
Total deferred charges and other assets | 939 | 1,119 |
Total Assets | 20,398 | 22,987 |
Current Liabilities: | ||
Securities due within one year | 515 | 157 |
Notes payable | 136 | 1,518 |
Energy marketing trade payables | 521 | 546 |
Accounts payable — | ||
Affiliated | 37 | 21 |
Other | 346 | 425 |
Customer deposits | 136 | 128 |
Accrued taxes — | ||
Accrued income taxes | 0 | 40 |
Other accrued taxes | 61 | 78 |
Accrued interest | 66 | 51 |
Accrued compensation | 71 | 74 |
Liabilities from risk management activities, net of collateral | 28 | 69 |
Other regulatory liabilities, current | 132 | 135 |
Other current liabilities | 122 | 159 |
Total current liabilities | 2,171 | 3,401 |
Long-term Debt | 5,393 | 5,891 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 944 | 1,089 |
Deferred credits related to income taxes | 930 | 1,063 |
Employee benefit obligations | 412 | 415 |
Accrued environmental remediation | 269 | 342 |
Other cost of removal obligations | 1,577 | 1,646 |
Other deferred credits and liabilities | 79 | 118 |
Total deferred credits and other liabilities | 4,211 | 4,673 |
Total Liabilities | 11,775 | 13,965 |
Common Stockholders' Equity: | ||
Common stock | 0 | 0 |
Paid-in capital | 8,863 | 9,214 |
Retained earnings (accumulated deficit) | (273) | (212) |
Accumulated other comprehensive income (loss) | 33 | 20 |
Total Common Stockholders' Equity | 8,623 | 9,022 |
Total Liabilities and Stockholders' Equity | $ 20,398 | $ 22,987 |
Condensed Consolidated Balanc_2
Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Other intangible assets, amortization | $ 225 | $ 186 |
Common stock, par value (in dollars per share) | $ 5 | $ 5 |
Common stock, shares authorized (in shares) | 1,500,000,000 | 1,500,000,000 |
Common stock, shares issued (in shares) | 1,000,000,000 | 1,000,000,000 |
Treasury shares at cost (in shares) | 1,000,000 | 900,000 |
ALABAMA POWER CO | ||
Common stock, par value (in dollars per share) | $ 40 | $ 40 |
Common stock, shares authorized (in shares) | 40,000,000 | 40,000,000 |
Common stock, shares outstanding (in shares) | 30,537,500 | 30,537,500 |
GEORGIA POWER CO | ||
Common stock, shares authorized (in shares) | 20,000,000 | 20,000,000 |
Common stock, shares outstanding (in shares) | 9,261,500 | 9,261,500 |
GULF POWER CO | ||
Common stock, shares authorized (in shares) | 20,000,000 | 20,000,000 |
Common stock, shares outstanding (in shares) | 7,392,717 | 7,392,717 |
MISSISSIPPI POWER CO | ||
Common stock, shares authorized (in shares) | 1,130,000 | 1,130,000 |
Common stock, shares outstanding (in shares) | 1,121,000 | 1,121,000 |
SOUTHERN POWER CO | ||
Other intangible assets, amortization | $ 66 | $ 47 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000 | 1,000,000 |
Common stock, shares outstanding (in shares) | 1,000 | 1,000 |
SOUTHERN Co GAS | ||
Other intangible assets, amortization | $ 133 | $ 120 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 100,000,000 | 100,000,000 |
Common stock, shares outstanding (in shares) | 100 | 100 |
Introduction
Introduction | 9 Months Ended |
Sep. 30, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
INTRODUCTION | INTRODUCTION The condensed quarterly financial statements of each registrant included herein have been prepared by such registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets as of December 31, 2017 have been derived from the audited financial statements of each registrant. In the opinion of each registrant's management, the information regarding such registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended September 30, 2018 and 2017 . Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each registrant believes that the disclosures regarding such registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year. Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the results of operations, financial position, or cash flows of any registrant. Recently Adopted Accounting Standards See Note 1 to the financial statements of the registrants under "Recently Issued Accounting Standards" in Item 8 of the Form 10-K for additional information. Revenue In 2014, the FASB issued ASC 606, Revenue from Contracts with Customers (ASC 606), replacing the existing accounting standard and industry-specific guidance for revenue recognition with a five-step model for recognizing and measuring revenue from contracts with customers. The underlying principle of the standard is to recognize revenue to depict the transfer of goods or services to customers at the amount expected to be collected. ASC 606 became effective on January 1, 2018 and the registrants adopted it using the modified retrospective method applied to open contracts and only to the version of the contracts in effect as of January 1, 2018. In accordance with the modified retrospective method, the registrants' previously issued financial statements have not been restated to comply with ASC 606 and the registrants did not have a cumulative-effect adjustment to retained earnings. The adoption of ASC 606 had no significant impact on the timing of revenue recognition compared to previously reported results; however, it requires enhanced disclosures regarding the nature, amount, timing, and uncertainty of revenue and the related cash flows arising from contracts with customers, which are included in Note (C). ASC 606 provided additional clarity on financial statement presentation that resulted in reclassifications into other revenues and other operations and maintenance from other income/(expense), net at Alabama Power and Georgia Power related to certain unregulated sales of products and services. In addition, contract assets related to certain fixed retail revenues at Georgia Power and Southern Company's unregulated distributed generation business have been reclassified from unbilled revenue in accordance with the guidance in ASC 606. These reclassifications did not affect the timing or amount of revenues recognized or cash flows. ASC 606 also provided additional guidance on revenue recognized over time, resulting in a change in the timing of revenue recognized from guaranteed and fixed billing arrangements at Southern Company Gas. The changes in natural gas revenues recognized in the third quarter and year-to-date 2018 relate primarily to the seasonal nature of natural gas usage. The net impact of accounting for revenue under ASC 606 decreased Southern Company's and Southern Company Gas' consolidated net income by $4 million for the three months ended September 30, 2018 and increased Southern Company's and Southern Company Gas' consolidated net income by $1 million for the nine months ended September 30, 2018 . The specific impacts of applying ASC 606 to revenues from contracts with customers on the financial statements of Southern Company, Alabama Power, Georgia Power, and Southern Company Gas compared to previously recognized guidance is shown below. For the Three Months Ended For the Nine Months Ended Condensed Statements of Income As Reported Balances Without Adoption of Effect of Change As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) (in millions) Southern Company Natural gas revenues $ 492 $ 497 $ (5 ) $ 2,806 $ 2,805 $ 1 Other revenues 199 198 1 1,007 1,003 4 Other operations and maintenance 1,404 1,387 17 4,217 4,178 39 Operating income 2,174 2,195 (21 ) 3,613 3,647 (34 ) Other income (expense), net 57 41 16 195 160 35 Earnings (loss) before income taxes 1,845 1,850 (5 ) 2,629 2,628 1 Income taxes (benefit) 623 624 (1 ) 598 598 — Consolidated net income (loss) 1,222 1,226 (4 ) 2,031 2,030 1 Consolidated net income (loss) attributable to Southern Company 1,164 1,168 (4 ) 1,948 1,947 1 Alabama Power Other revenues $ 68 $ 59 $ 9 $ 199 $ 173 $ 26 Other operations and maintenance 401 390 11 1,191 1,159 32 Operating income 561 563 (2 ) 1,313 1,319 (6 ) Other income (expense), net 9 7 2 24 18 6 Georgia Power Other revenues $ 121 $ 97 $ 24 $ 349 $ 287 $ 62 Other operations and maintenance 460 437 23 1,325 1,268 57 Operating income (loss) 991 990 1 1,032 1,027 5 Other income (expense), net 30 31 (1 ) 104 109 (5 ) Southern Company Gas Natural gas revenues $ 487 $ 492 $ (5 ) $ 2,829 $ 2,828 $ 1 Operating income 374 379 (5 ) 810 809 1 Earnings before income taxes 362 367 (5 ) 769 768 1 Income taxes 316 317 (1 ) 475 475 — Net income (loss) 46 50 (4 ) 294 293 1 For the Nine Months Ended Condensed Statements of Cash Flows As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Consolidated net income $ 2,031 $ 2,030 $ 1 Changes in certain current assets and liabilities: Receivables 37 27 10 Other current assets (90 ) (80 ) (10 ) Other current liabilities (67 ) (68 ) 1 Georgia Power Changes in certain current assets and liabilities: Receivables $ (205 ) $ (242 ) $ 37 Other current assets (36 ) 1 (37 ) Southern Company Gas Net income $ 294 $ 293 $ 1 Changes in certain current assets and liabilities: Other current liabilities 35 34 1 At September 30, 2018 Condensed Balance Sheets As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Unbilled revenues $ 738 $ 776 $ (38 ) Other accounts and notes receivable 690 691 (1 ) Other current assets 232 193 39 Other current liabilities 763 764 (1 ) Retained earnings 9,048 9,047 1 Georgia Power Unbilled revenues $ 245 $ 310 $ (65 ) Other accounts and notes receivable 96 97 (1 ) Other current assets 91 25 66 Southern Company Gas Other current liabilities 122 123 (1 ) Accumulated deficit (273 ) (274 ) 1 Other In 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (ASU 2016-18). ASU 2016-18 eliminates the need to reflect transfers between cash and restricted cash in operating, investing, and financing activities in the statements of cash flows. In addition, the net change in cash and cash equivalents during the period includes amounts generally described as restricted cash or restricted cash equivalents. The registrants adopted ASU 2016-18 effective January 1, 2018 with no material impact on their financial statements. Southern Company, Southern Power, and Southern Company Gas retrospectively applied ASU 2016-18 effective January 1, 2018 and have restated prior periods in the statements of cash flows by immaterial amounts. The change in restricted cash in the statements of cash flows was previously disclosed in operating activities for Southern Company and Southern Company Gas and in investing activities for Southern Company and Southern Power. See " Restricted Cash " herein for additional information. In March 2017, the FASB issued ASU No. 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (ASU 2017-07). ASU 2017-07 requires that an employer report the service cost component in the same line item or items as other compensation costs and requires the other components of net periodic pension and postretirement benefit costs to be separately presented in the statements of income outside of income from operations. Additionally, only the service cost component is eligible for capitalization, when applicable. The registrants adopted ASU 2017-07 effective January 1, 2018 with no material impact on their financial statements. ASU 2017-07 has been applied retrospectively for the presentation of the service cost component and the other components of net periodic benefit costs in the statements of income for Southern Company, the traditional electric operating companies, and Southern Company Gas. Since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017, no retrospective presentation of Southern Power's net periodic benefits costs is required. The requirement to limit capitalization to the service cost component of net periodic benefit costs has been applied on a prospective basis from the date of adoption for all registrants. The presentation changes resulted in a decrease in operating income and an increase in other income for the three and nine months ended September 30, 2018 and 2017 for Southern Company, the traditional electric operating companies, and Southern Company Gas. In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities (ASU 2017-12). ASU 2017-12 makes more financial and non-financial hedging strategies eligible for hedge accounting, amends the related presentation and disclosure requirements, and simplifies hedge effectiveness assessment requirements. ASU 2017-12 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The registrants adopted ASU 2017-12 effective January 1, 2018 with no material impact on their financial statements. See Note (I) for disclosures required by ASU 2017-12. On February 14, 2018, the FASB issued ASU No. 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income (ASU 2018-02) to address the application of ASC 740, Income Taxes (ASC 740) to certain provisions of the Tax Reform Legislation. ASU 2018-02 specifically addresses the ASC 740 requirement that the effect of a change in tax laws or rates on deferred tax assets and liabilities be included in income from continuing operations, even when the tax effects were initially recognized directly in OCI at the previous rate, which strands the income tax rate differential in accumulated OCI. The amendments in ASU 2018-02 allow a reclassification from accumulated OCI to retained earnings for stranded tax effects resulting from the Tax Reform Legislation. The registrants adopted ASU 2018-02 effective January 1, 2018 with no material impact on their financial statements. Asset Retirement Obligations See Note 1 to the financial statements of Southern Company and the traditional electric operating companies under "Asset Retirement Obligations and Other Costs of Removal" in Item 8 of the Form 10-K for additional information regarding each company's AROs and the EPA's Disposal of Coal Combustion Residuals from Electric Utilities final rule (CCR Rule). As of September 30, 2018 , details of the AROs, including those related to the CCR Rule, included in the condensed balance sheets of Southern Company, Alabama Power, Georgia Power, Gulf Power, and Mississippi Power were as follows: Southern Company Alabama Power Georgia Power Gulf Mississippi Power (in millions) Balance at December 31, 2017 $ 4,824 $ 1,709 $ 2,638 $ 142 $ 174 Liabilities incurred 2 — — — — Liabilities settled (160 ) (31 ) (82 ) (23 ) (22 ) Accretion 153 72 70 3 4 Cash flow revisions 1,510 1,451 (32 ) 42 21 Reclassification to held for sale (164 ) — — — — Balance at September 30, 2018 $ 6,165 $ 3,201 $ 2,594 $ 164 $ 177 In June 2018, Alabama Power recorded an increase of approximately $1.2 billion to its AROs related to the CCR Rule. Mississippi Power also recorded an increase of approximately $11 million to its AROs related to an ash pond at Plant Greene County, which is jointly-owned with Alabama Power. The revised cost estimates were based on information from feasibility studies performed on ash ponds in use at plants operated by Alabama Power, including Plant Greene County. During the second quarter 2018, Alabama Power's management completed its analysis of these studies which indicated that additional closure costs, primarily related to increases in estimated ash volume, water management requirements, and design revisions, will be required to close these ash ponds under the planned closure-in-place methodology. As the level of work becomes more defined in the next 12 months, it is likely that these cost estimates will change and the change could be material. Georgia Power continues to perform engineering studies related to its plans to close the ash ponds at all of its generating plants, including Plant Scherer Unit 3, which is jointly owned with Gulf Power, in compliance with federal and state CCR rules. Georgia Power also continues to refine its closure strategy and cost estimates for each ash pond and is preparing permit applications as required by the State of Georgia CCR rule. While Georgia Power and Gulf Power believe their recorded liabilities for ash pond closures appropriately reflect their obligations under the current closure strategies they have elected, changes to such strategies and cost estimates would likely result in additional closure costs which would increase their ARO liabilities. It is not currently possible to quantify the impacts of any increase related to a change in closure strategies and/or ongoing engineering studies for the current closure strategies, and the timing of future cash outflows is indeterminable at this time; however, the impact on Georgia Power's and Gulf Power's ARO liabilities is expected to be material. As permit applications advance, engineering studies continue, and the timing of individual ash pond closures develops further during the fourth quarter 2018, Georgia Power and Gulf Power will record any necessary changes to their ARO liabilities. The traditional electric operating companies expect to continue to periodically update their ARO cost estimates, which could increase further, as additional information becomes available. Absent continued recovery of ARO costs through regulated rates, Southern Company's and the traditional electric operating companies' results of operations, cash flows, and financial condition could be materially impacted. The ultimate outcome of this matter cannot be determined at this time. In June 2018, Alabama Power completed an updated decommissioning cost site study for Plant Farley. The estimated cost of decommissioning based on the study resulted in an increase in Southern Company's and Alabama Power's ARO liability of approximately $300 million . See " Nuclear Decommissioning " below for additional information. Georgia Power expects to complete updated decommissioning cost site studies for Plant Hatch and Plant Vogtle Units 1 and 2 in the fourth quarter 2018, which could result in additional changes to Southern Company's and Georgia Power's ARO liability. The ultimate outcome of these studies cannot be determined at this time. The reclassification of a portion of the ARO liability to liabilities held for sale by Southern Company represents the AROs related to Gulf Power. See Note (J) under " Southern Company's Sale of Gulf Power " and " Assets Held for Sale " for additional information. Nuclear Decommissioning See Note 1 to the financial statements of Southern Company and Alabama Power under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information. In June 2018, Alabama Power completed an updated decommissioning cost site study for Plant Farley. The estimated costs of decommissioning based on the 2018 site study are as follows: Decommissioning periods: Beginning year 2037 Completion year 2076 (in millions) Site study costs: Radiated structures $ 1,621 Non-radiated structures 99 Total site study costs $ 1,720 The decommissioning cost estimates are based on prompt dismantlement and removal of the plant from service. The actual decommissioning costs may vary from the above estimates because of changes in the assumed date of decommissioning, changes in NRC requirements, or changes in the assumptions used in making these estimates. For ratemaking purposes, Alabama Power's decommissioning costs are based on the site study. Significant assumptions used to determine these costs for ratemaking were an inflation rate of 4.5% and a trust earnings rate of 7.0% . The next site study is expected to be completed in 2023 . Amounts previously contributed to the external trust funds are currently projected to be adequate to meet the updated decommissioning obligations. Alabama Power will continue to provide site specific estimates of the decommissioning costs and related projections of funds in the external trust to the Alabama PSC and, if necessary, would seek the Alabama PSC's approval to address any changes in a manner consistent with the NRC and other applicable requirements. Goodwill and Other Intangible Assets The following table presents year-to-date changes in goodwill balances for Southern Company and Southern Company Gas: Goodwill Southern Company Southern Company Gas Gas Distribution Operations Gas Marketing Services Total (in millions) Balance at December 31, 2017 $ 6,268 $ 4,702 $ 1,265 $ 5,967 Impairment (a) (42 ) — (42 ) (42 ) Dispositions (b) (910 ) (668 ) (242 ) (910 ) Balance at September 30, 2018 $ 5,315 (c) $ 4,034 $ 981 $ 5,015 (a) On April 11, 2018, Southern Company Gas entered into a stock purchase agreement for the sale of Pivotal Home Solutions. In contemplation of the transaction, a goodwill impairment charge of $42 million was recorded in the first quarter 2018. See Note (J) under " Southern Company Gas " for additional information. (b) Gas distribution operations reflects goodwill allocated to Elizabethtown Gas, Elkton Gas, and Florida City Gas, which were sold during the third quarter 2018. Gas marketing services reflects goodwill associated with Pivotal Home Solutions, which was sold on June 4, 2018. See Note (J) under " Southern Company Gas " for additional information. (c) Total does not add due to rounding. Goodwill is not amortized but is subject to an annual impairment test during the fourth quarter of each year or more frequently if impairment indicators arise. Other intangible assets were as follows: At September 30, 2018 At December 31, 2017 Gross Carrying Amount Accumulated Amortization Other Intangible Assets, Net Gross Carrying Amount Accumulated Amortization Other (in millions) (in millions) Southern Company Other intangible assets subject to amortization: Customer relationships (*) $ 223 $ (87 ) $ 136 $ 288 $ (83 ) $ 205 Trade names (*) 70 (18 ) 52 159 (17 ) 142 Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 PPA fair value adjustments 456 (66 ) 390 456 (47 ) 409 Other 11 (5 ) 6 17 (5 ) 12 Total other intangible assets subject to amortization $ 824 $ (225 ) $ 599 $ 984 $ (186 ) $ 798 Other intangible assets not subject to amortization: Federal Communications Commission licenses 75 — 75 75 — 75 Total other intangible assets $ 899 $ (225 ) $ 674 $ 1,059 $ (186 ) $ 873 Southern Power Other intangible assets subject to amortization: PPA fair value adjustments $ 456 $ (66 ) $ 390 $ 456 $ (47 ) $ 409 Southern Company Gas Other intangible assets subject to amortization: Gas marketing services (*) Customer relationships $ 156 $ (78 ) $ 78 $ 221 $ (77 ) $ 144 Trade names 26 (6 ) 20 115 (9 ) 106 Wholesale gas services Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 Total other intangible assets subject to amortization $ 246 $ (133 ) $ 113 $ 400 $ (120 ) $ 280 (*) Balances as of September 30, 2018 reflect Southern Company Gas' sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas – Sale of Pivotal Home Solutions " for additional information. Amortization associated with other intangible assets was as follows: Three Months Ended Nine Months Ended September 30, 2018 (in millions) Southern Company $ 21 $ 70 Southern Power $ 6 $ 19 Southern Company Gas $ 12 $ 42 Restricted Cash The registrants adopted ASU 2016-18 as of January 1, 2018. See " Recently Adopted Accounting Standards – Other " herein for additional information. At December 31, 2017 , Southern Power had restricted cash primarily related to certain acquisitions and construction projects. At both September 30, 2018 and December 31, 2017 , Southern Company Gas had restricted cash held as collateral for worker's compensation, life insurance, and long-term disability insurance. The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at September 30, 2018 and/or December 31, 2017 : Southern Company Southern Company Gas (in millions) At September 30, 2018 Cash and cash equivalents $ 1,847 $ 56 Cash and cash equivalents classified as assets held for sale 37 — Restricted cash: Other accounts and notes receivable 6 6 Total cash, cash equivalents, and restricted cash $ 1,891 (*) $ 62 (*) Total does not add due to rounding. Southern Company Southern Power Southern Company Gas (in millions) At December 31, 2017 Cash and cash equivalents $ 2,130 $ 129 $ 73 Restricted cash: Other accounts and notes receivable 5 — 5 Deferred charges and other assets 12 11 — Total cash, cash equivalents, and restricted cash $ 2,147 $ 140 $ 78 Natural Gas for Sale Southern Company Gas' natural gas distribution utilities, with the exception of Nicor Gas, carry natural gas inventory on a WACOG basis. 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. Southern Company Gas had no inventory decrement at September 30, 2018 . 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. Natural gas inventories for Southern Company Gas' non-utility businesses are carried at the lower of weighted average cost or current market price, with cost determined on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Southern Company Gas had no material LOCOM adjustment in any period presented. Hypothetical Liquidation at Book Value Southern Power has consolidated renewable generation projects that are partially funded by a third-party tax equity investor. The related contractual provisions represent profit-sharing arrangements because the allocations of cash distributions and tax benefits are not based on fixed ownership percentages. Therefore, the noncontrolling interest is accounted for under a balance sheet approach utilizing the hypothetical liquidation at book value (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 hypothetical liquidation at the end of the period compared to the beginning of the period. |
Contingencies and Regulatory Ma
Contingencies and Regulatory Matters | 9 Months Ended |
Sep. 30, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
CONTINGENCIES AND REGULATORY MATTERS | CONTINGENCIES AND REGULATORY MATTERS See Note 3 to the financial statements of the registrants in Item 8 of the Form 10-K for information relating to various lawsuits, other contingencies, and regulatory matters. General Litigation Matters Each registrant is subject to certain claims and legal actions arising in the ordinary course of business. In addition, the business activities of Southern Company's subsidiaries are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO 2 and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters. The ultimate outcome of such pending or potential litigation against each registrant and any subsidiaries cannot be predicted 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. Southern Company In January 2017, a putative securities class action complaint was filed against Southern Company, certain of its officers, and certain former Mississippi Power officers in the U.S. District Court for the Northern District of Georgia, Atlanta Division, by Monroe County Employees' Retirement System on behalf of all persons who purchased shares of Southern Company's common stock between April 25, 2012 and October 29, 2013. The complaint alleges that Southern Company, certain of its officers, and certain former Mississippi Power officers made materially false and misleading statements regarding the Kemper County energy facility in violation of certain provisions under the Securities Exchange Act of 1934, as amended. The complaint seeks, among other things, compensatory damages and litigation costs and attorneys' fees. In June 2017, the plaintiffs filed an amended complaint that provided additional detail about their claims, increased the purported class period by one day, and added certain other former Mississippi Power officers as defendants. In July 2017, the defendants filed a motion to dismiss the plaintiffs' amended complaint with prejudice, to which the plaintiffs filed an opposition in September 2017. On March 29, 2018, the U.S. District Court for the Northern District of Georgia, Atlanta Division, issued an order granting, in part, the defendants' motion to dismiss. The court dismissed certain claims against certain officers of Southern Company and Mississippi Power and dismissed the allegations related to a number of the statements that plaintiffs challenged as being false or misleading. On April 26, 2018, the defendants filed a motion for reconsideration of the court's order, seeking dismissal of the remaining claims in the lawsuit. On August 10, 2018, the court denied the motion for reconsideration and denied a motion to certify the issue for interlocutory appeal. In February 2017, Jean Vineyard filed a shareholder derivative lawsuit and, in May 2017, Judy Mesirov filed a shareholder derivative lawsuit, each in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. In August 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties. Each plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. Each plaintiff also seeks certain changes to Southern Company's corporate governance and internal processes. On April 25, 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action. In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, State of Georgia that names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. The plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and disgorgement of profits and, on its behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiff also seeks certain unspecified changes to Southern Company's corporate governance and internal processes. On May 4, 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action. Southern Company believes these legal challenges have no merit; however, an adverse outcome in any of these proceedings could have an impact on Southern Company's results of operations, financial condition, and liquidity. Southern Company will vigorously defend itself in these matters, the ultimate outcome of which cannot be determined at this time. Alabama Power On March 2, 2018, the Alabama Department of Environmental Management (ADEM) issued proposed administrative orders assessing a penalty of $1.25 million to Alabama Power for unpermitted discharge of fluids and/or pollutants to groundwater at five electric generating plants. The orders were finalized and Alabama Power paid the penalty on September 27, 2018. This matter is now concluded. Georgia Power In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of municipal franchise fees (all of which are remitted to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state tort law claims. In 2016, the Georgia Court of Appeals reversed the trial court's previous dismissal of the case and remanded the case to the trial court. Georgia Power filed a petition for writ of certiorari with the Georgia Supreme Court, which was granted in August 2017. On June 18, 2018, the Georgia Supreme Court affirmed the judgment of the Georgia Court of Appeals and remanded the case to the trial court for further proceedings. On August 27, 2018, Georgia Power filed a motion to stay the case and requested the trial court refer the case to the Georgia PSC for a declaratory ruling. Georgia Power believes the plaintiffs' claims have no merit and will continue to vigorously defend itself in this matter. The amount of any possible losses cannot be calculated at this time because, among other factors, it is unknown whether any class will ultimately be certified; the scope of such a class, if certified; and whether any losses would be subject to recovery from any municipalities. The ultimate outcome of this matter cannot be determined at this time. Mississippi Power In 2016, a complaint against Mississippi Power was filed in Harrison County Circuit Court (Circuit Court) by Biloxi Freezing & Processing Inc., Gulfside Casino Partnership, and John Carlton Dean, which was amended and refiled to include, among other things, Southern Company as a defendant. The individual plaintiff alleged that Mississippi Power and Southern Company violated the Mississippi Unfair Trade Practices Act. All plaintiffs alleged that Mississippi Power and Southern Company concealed, falsely represented, and failed to fully disclose important facts concerning the cost and schedule of the Kemper County energy facility and that these alleged breaches unjustly enriched Mississippi Power and Southern Company. The plaintiffs sought unspecified actual damages and punitive damages; asked the Circuit Court to appoint a receiver to oversee, operate, manage, and otherwise control all affairs relating to the Kemper County energy facility; asked the Circuit Court to revoke any licenses or certificates authorizing Mississippi Power or Southern Company to engage in any business related to the Kemper County energy facility in Mississippi; and sought attorney's fees, costs, and interest. The plaintiffs also sought an injunction to prevent any Kemper County energy facility costs from being charged to customers through electric rates. In June 2017, the Circuit Court ruled in favor of motions by Southern Company and Mississippi Power and dismissed the case. In July 2017, the plaintiffs filed notice of an appeal. On July 13, 2018, Mississippi Power and Southern Company reached a settlement agreement with the plaintiffs and the plaintiffs' appeal was dismissed with prejudice. The settlement had no material impact on Southern Company's or Mississippi Power's financial statements. On May 18, 2018, Southern Company and Mississippi Power received a notice of dispute and arbitration demand filed by Martin Product Sales, LLC (Martin) based on two agreements, both related to Kemper IGCC byproducts for which Mississippi Power provided termination notices in September 2017. Martin alleges breach of contract, breach of good faith and fair dealing, fraud and misrepresentation, and civil conspiracy and makes a claim for damages in the amount of approximately $143 million , as well as additional unspecified damages, attorney's fees, costs, and interest. Southern Company and Mississippi Power believe this legal challenge has no merit; however, an adverse outcome in this proceeding could have a material impact on Southern Company's and Mississippi Power's results of operations, financial condition, and liquidity. Southern Company and Mississippi Power will vigorously defend themselves in this matter, the ultimate outcome of which cannot be determined at this time. On May 14, 2018, Mississippi Power's claim for lost revenue resulting from the Deepwater Horizon oil spill in the Gulf of Mexico in 2010 was settled. The settlement proceeds of $18 million , net of expenses and income tax, are included in Southern Company's and Mississippi Power's earnings for the nine months ended September 30, 2018. Southern Power Southern Power indirectly owns a 51% membership interest in RE Roserock LLC (Roserock), the owner of the Roserock facility in Pecos County, Texas. Prior to the facility being placed in service in November 2016, certain solar panels were damaged during installation by the construction contractor, McCarthy Building Companies, Inc. (McCarthy), and certain solar panels were damaged by a hail event that also occurred during construction. In May 2017, Roserock filed a lawsuit in the state district court in Pecos County, Texas, (State Court lawsuit) against XL Insurance America, Inc. (XL) and North American Elite Insurance Company (North American Elite) seeking recovery from an insurance policy for damages resulting from the hail storm and McCarthy's installation practices. On June 1, 2018, the court in the State Court lawsuit granted Roserock's motion for partial summary judgment, finding that the insurers were in breach of contract and in violation of the Texas Insurance Code for failing to pay any monies owed for the hail claim. In addition to the State Court lawsuit, lawsuits were filed between Roserock and McCarthy, as well as other parties, and that litigation has been consolidated in the U.S. District Court for the Western District of Texas. Southern Power intends to vigorously pursue and defend these matters, the ultimate outcome of which cannot be determined at this time. Southern Company Gas Nicor Energy Services Company, doing business as Pivotal Home Solutions, formerly a wholly-owned subsidiary of Southern Company Gas, was a defendant in a putative class action initially filed in 2017 in the state court in Indiana. The plaintiffs purported to represent a class of the customers who purchased products from Nicor Energy Services Company and alleged that the marketing, sale, and billing of the products violated the Indiana Consumer Fraud and Deceptive Business Practices Act, constituting common law fraud and resulting in unjust enrichment of these entities. In 2018, Nicor Energy Services Company was named in a second class action filed in the state court of Ohio asserting nearly identical allegations and legal claims. The plaintiffs sought, on behalf of the classes they purported to represent, actual and punitive damages, interest costs, attorney fees, and injunctive relief. To facilitate the sale of Pivotal Home Solutions, Southern Company Gas retained most of the financial responsibility for these lawsuits following the completion of the sale. On June 12, 2018, the parties settled these claims and Southern Company Gas recorded an $11 million charge, which is included in other operations and maintenance expenses for the nine months ended September 30, 2018. Environmental Matters 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 in Illinois and Georgia have all received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental compliance costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable state regulatory agencies. Georgia Power's environmental remediation liability was $25 million and $22 million as of September 30, 2018 and December 31, 2017 , respectively. 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. Gulf Power's environmental remediation liability includes estimated costs of environmental remediation projects of approximately $48 million and $52 million as of September 30, 2018 and December 31, 2017 , respectively. These estimated costs primarily relate to site closure criteria by the Florida Department of Environmental Protection (FDEP) for potential impacts to soil and groundwater from herbicide applications at Gulf Power's substations. The schedule for completion of the remediation projects is subject to FDEP approval. At September 30, 2018 , Southern Company Gas' environmental remediation liability was $294 million based on the estimated cost of environmental investigation and remediation associated with known current and former manufactured gas plant operating sites. At December 31, 2017 , Southern Company Gas' total environmental remediation liability was $388 million , of which $85 million related to Elizabethtown Gas, which was sold on July 1, 2018. These environmental remediation expenditures are recoverable from customers through rate mechanisms approved by the applicable state regulatory agencies of the natural gas distribution utilities, with the exception of one site representing $2 million of the total accrued remediation costs. See Note (J) under " Southern Company Gas " for information regarding Southern Company Gas' sale of Elizabethtown Gas. 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 Southern Company, Georgia Power, Gulf Power, or Southern Company Gas. FERC Matters Market-Based Rate Authority See Note 3 to the financial statements of Southern Company, the traditional electric operating companies, and Southern Power under "FERC Matters" in Item 8 of the Form 10-K for additional information regarding proceedings related to the traditional electric operating companies' and Southern Power's 2014 and 2017 triennial market power analyses. On May 4, 2018, the FERC issued an order terminating both proceedings, finding that the traditional electric operating companies and Southern Power satisfy the FERC's standards for market-based rates. On May 9, 2018, the traditional electric operating companies and Southern Power made the compliance filing required by the order. These proceedings are concluded. Open Access Transmission Tariff On May 10, 2018, the Alabama Municipal Electric Authority and Cooperative Energy filed with the FERC a complaint against SCS and the traditional electric operating companies claiming that the current 11.25% base ROE used in calculating the annual transmission revenue requirements of the traditional electric operating companies' open access transmission tariff is unjust and unreasonable as measured by the applicable FERC standards. The complaint requests that the base ROE be set no higher than 8.65% and that the FERC order refunds for the difference in revenue requirements that results from applying a just and reasonable ROE established in this proceeding upon determining the current ROE is unjust and unreasonable. On June 18, 2018, SCS and the traditional electric operating companies filed their response challenging the adequacy of the showing presented by the complainants and offering support for the current ROE. On September 6, 2018, the FERC issued an order establishing a refund effective date of May 10, 2018 in the event a refund is due and initiating an investigation and settlement procedures regarding the current base ROE. Through September 30, 2018, the estimated maximum potential refund is not expected to be material to Southern Company's or the traditional electric operating companies' results of operations. The ultimate outcome of this matter cannot be determined at this time. Fuel Cost Recovery See Note 3 to the financial statements of Mississippi Power under "FERC Matters – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information. Mississippi Power has a wholesale MRA and a Market Based (MB) fuel cost recovery factor. At September 30, 2018 , the amount of over-recovered wholesale MRA fuel costs included in other regulatory liabilities, current on the condensed balance sheet was approximately $7 million compared to an immaterial amount at December 31, 2017. Under-recovered wholesale MB fuel costs included in the balance sheets were immaterial at September 30, 2018 and December 31, 2017. Cooperative Energy Power Supply Agreement See Note 3 to the financial statements of Mississippi Power under "FERC Matters – Cooperative Energy Power Supply Agreement" in Item 8 of the Form 10-K for additional information regarding Cooperative Energy's network integration transmission service agreement (NITSA) with SCS. On March 23, 2018, the FERC accepted the amendment to the NITSA between Cooperative Energy and SCS, effective April 1, 2018. Regulatory Matters Alabama Power See Note 3 to the financial statements of Southern Company and Alabama Power under "Regulatory Matters – Alabama Power" and "Retail Regulatory Matters," respectively, in Item 8 of the Form 10-K for additional information regarding Alabama Power's recovery of retail costs through various regulatory clauses and accounting orders. The balance of each regulatory clause recovery on the balance sheet follows: Regulatory Clause Balance Sheet Line Item September 30, December 31, (in millions) Rate CNP Compliance Deferred under recovered regulatory clause revenues $ — $ 17 Under recovered regulatory clause revenues 7 — Rate CNP PPA Deferred under recovered regulatory clause revenues 30 12 Retail Energy Cost Recovery Deferred under recovered regulatory clause revenues 58 25 Under recovered regulatory clause revenues 41 — Natural Disaster Reserve Other regulatory liabilities, deferred 24 38 On May 1, 2018, the Alabama PSC approved modifications to Rate RSE and other commitments designed to position Alabama Power to address the growing pressure on its credit quality resulting from the Tax Reform Legislation, without increasing retail rates under Rate RSE in the near term. Alabama Power plans 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 September 30, 2018, Alabama Power's equity ratio was approximately 47% . Rate RSE The approved modifications to Rate RSE became effective June 2018 and are applicable for January 2019 billings and thereafter. The modifications include reducing the top of the allowed weighted common equity return (WCER) range from 6.21% to 6.15% and modifications to the refund mechanism applicable to prior year actual results. The modifications to the refund mechanism allow Alabama Power to retain a portion of the revenue that causes the actual WCER for a given year to exceed the allowed range. Generally, if Alabama Power's actual WCER range 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% . In conjunction with these modifications to Rate RSE, on May 8, 2018, Alabama Power consented to a moratorium on any upward adjustments under Rate RSE for 2019 and 2020. Additionally, Alabama Power will return $50 million to customers through bill credits in 2019. In accordance with an established retail tariff that provides for an interim adjustment to customer billings to recognize the impact of a change in the statutory income tax rate, Alabama Power has returned $151 million through September 30, 2018 and anticipates returning a total of approximately $257 million to retail customers through bill credits by December 31, 2018 as a result of the change in the federal income tax rate under the Tax Reform Legislation. Rate ECR On May 1, 2018, the Alabama PSC approved an increase to Rate ECR from 2.015 cents per KWH to 2.353 cents per KWH effective July 2018 which is expected to result in additional collections of approximately $100 million through December 31, 2018. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery in 2018. Absent any further order from the Alabama PSC, in January 2019, the rate will return to the originally authorized 5.910 cents per KWH. Accounting Order On May 1, 2018, the Alabama PSC approved an accounting order that authorizes Alabama Power to defer the benefits of federal excess deferred income taxes associated with the Tax Reform Legislation for the year ending December 31, 2018 as a regulatory liability and to use up to $30 million of such deferrals to offset under recovered amounts under Rate ECR. Any remaining amounts will be used for the benefit of customers as determined by the Alabama PSC. As of September 30, 2018, Alabama Power had applied the full $30 million to offset the under recovered balance under Rate ECR and expects the total deferrals for the year ending December 31, 2018 to be approximately $50 million . See Note 5 to the financial statements of Southern Company and Alabama Power under "Federal Tax Reform Legislation" and of Alabama Power under "Current and Deferred Income Taxes" in Item 8 of the Form 10-K for additional information. Plant Greene County Alabama Power jointly owns Plant Greene County with an affiliate, Mississippi Power. See Note 4 to the financial statements of Alabama Power in Item 8 of the Form 10-K for additional information regarding the joint ownership agreement. On August 6, 2018, Mississippi Power filed its proposed Reserve Margin Plan (RMP) with the Mississippi PSC, which proposes a four -year acceleration of the retirement of Plant Greene County Units 1 and 2 to the third quarter 2021 and the third quarter 2022, respectively. Mississippi Power's proposed Plant Greene County unit retirements would require the completion of proposed transmission and system reliability improvements, as well as agreement by Alabama Power. Alabama Power will monitor Mississippi Power's proposed RMP and associated regulatory process as well as the proposed transmission and system reliability improvements. Alabama Power will review all the facts and circumstances and will evaluate all its alternatives prior to reaching a final determination on the ongoing operations of Plant Greene County. The ultimate outcome of this matter cannot be determined at this time. 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 currently recovers its costs from the regulated retail business through the 2013 ARP, which includes traditional base tariff rates, Demand-Side Management tariffs, Environmental Compliance Cost Recovery tariffs, and Municipal Franchise Fee tariffs. In addition, financing costs related to certified construction costs of Plant Vogtle Units 3 and 4 are being collected through the NCCR tariff and fuel costs are collected through a separate fuel cost recovery tariff. See " Nuclear Construction " herein and Note 3 to the financial statements of Southern Company under "Nuclear Construction" and Georgia Power under "Retail Regulatory Matters – Nuclear Construction" in Item 8 of the Form 10-K for additional information regarding the NCCR tariff. Also see " Fuel Cost Recovery " herein and Note 3 to the financial statements of Southern Company under "Regulatory Matters – Georgia Power – Fuel Cost Recovery" and Georgia Power under "Retail Regulatory Matters – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information regarding fuel cost recovery. Rate Plans See Note 3 to the financial statements of Southern Company and Georgia Power under "Regulatory Matters – Georgia Power – Rate Plans" and "Retail Regulatory Matters – Rate Plans," respectively, in Item 8 of the Form 10-K for additional information regarding Georgia Power's 2013 ARP and the Georgia PSC's 2018 order related to the Tax Reform Legislation. On April 3, 2018, the Georgia PSC approved a settlement agreement between Georgia Power and the staff of the Georgia PSC regarding the retail rate impact of the Tax Reform Legislation (Georgia Power Tax Reform Settlement Agreement). Pursuant to the Georgia Power Tax Reform Settlement Agreement, to reflect the federal income tax rate reduction impact of the Tax Reform Legislation, Georgia Power will refund to customers a total of $330 million through bill credits. Georgia Power issued bill credits of approximately $130 million in October 2018 and will issue bill credits of approximately $95 million in June 2019 and $105 million in February 2020. In addition, Georgia Power is deferring as a regulatory liability (i) the revenue equivalent of the tax expense reduction resulting from legislation lowering the Georgia state income tax rate from 6.00% to 5.75% in 2019 and (ii) the entire benefit of approximately $700 million in federal and state excess accumulated deferred income taxes. At September 30, 2018 , Georgia Power's related regulatory liability balance totaled $655 million . The amortization of these regulatory liabilities is expected to be addressed in Georgia Power's next base rate case, which is scheduled to be filed by July 1, 2019. If there is not a base rate case in 2019, customers will receive $185 million in annual bill credits beginning in 2020, with any additional federal and state income tax savings deferred as a regulatory liability, until Georgia Power's next base rate case. To address the negative cash flow and credit metric impacts of the Tax Reform Legislation, the Georgia PSC also approved an increase in Georgia Power's retail equity ratio to the lower of (i) Georgia Power's actual common equity weight in its capital structure or (ii) 55% , until Georgia Power's next base rate case. At September 30, 2018 , Georgia Power's actual retail common equity ratio (on a 13 -month average basis) was approximately 53% . Benefits from reduced federal income tax rates in excess of the amounts refunded to customers will be retained by Georgia Power to cover the carrying costs of the incremental equity in 2018 and 2019. Fuel Cost Recovery As of September 30, 2018 and December 31, 2017 , Georgia Power's under recovered fuel balance totaled $105 million and $165 million , respectively, and is included as under recovered fuel clause revenues on Southern Company's and Georgia Power's condensed balance sheets. On August 16, 2018, the Georgia PSC approved the deferral of Georgia Power's next fuel case to no later than March 16, 2020, with rates to be effective June 1, 2020. Georgia Power continues to be allowed to adjust its fuel cost recovery rates under an interim fuel rider prior to the next fuel case if the under or over recovered fuel balance exceeds $200 million . Fuel cost recovery revenues 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 cash flow. Storm Damage Recovery See Note 3 to the financial statements of Southern Company under "Regulatory Matters – Georgia Power – Storm Damage Recovery" and Note 1 to the financial statements of Georgia Power under "Storm Damage Recovery" in Item 8 of the Form 10-K for additional information regarding Georgia Power's storm damage reserve. Georgia Power is accruing $30 million annually through December 31, 2019, as provided in the 2013 ARP, for incremental operations and maintenance costs of damage from major storms to its transmission and distribution facilities. As of September 30, 2018, the total balance in Georgia Power's regulatory asset related to storm damage was $311 million . During October 2018, Hurricane Michael caused significant damage to Georgia Power's transmission and distribution facilities. Georgia Power currently estimates the costs of repairing the damage will total approximately $125 million to $150 million , which will be charged to Georgia Power's storm damage reserve or capitalized . The rate of storm damage cost recovery is expected to be adjusted as part of Georgia Power's next base rate case, which is scheduled to be filed by July 1, 2019. The ultimate outcome of this matter cannot be determined at this time. Gulf Power See Note 3 to the financial statements of Gulf Power under "Retail Regulatory Matters" in Item 8 of the Form 10-K for additional information regarding Gulf Power's rates and charges for service to retail customers. Storm Damage Cost Recovery See Note 1 to the financial statements of Gulf Power under "Property Damage Reserve" in Item 8 of the Form 10-K for information on how Gulf Power maintains a reserve for property damage to cover the cost of damages from major storms to its transmission and distribution lines and the cost of uninsured damages to its generating facilities and other property. On October 10, 2018, Hurricane Michael made landfall on the Gulf Coa |
Revenue from Contracts with Cus
Revenue from Contracts with Customers | 9 Months Ended |
Sep. 30, 2018 | |
Revenue from Contract with Customer [Abstract] | |
Revenue from Contracts with Customers | REVENUE FROM CONTRACTS WITH CUSTOMERS The registrants generate revenues from a variety of sources, some of which are excluded from the scope of ASC 606, such as leases, derivatives, and certain cost recovery mechanisms. See Note (A) under " Recently Adopted Accounting Standards – Revenue " for additional information on the adoption of ASC 606 for revenue from contracts with customers. The majority of the revenues of the traditional electric operating companies and Southern Company Gas are generated from contracts with retail electric and natural gas distribution customers. Revenues from this integrated service to deliver electricity or gas when and if called upon by the customer is recognized as a single performance obligation satisfied over time and is recognized at a tariff rate as electricity or gas is delivered to the customer during the month. The traditional electric operating companies and Southern Company Gas exclude taxes imposed on the customer and collected on behalf of governmental agencies to be remitted to these agencies from the transaction price in determining the revenue related to contracts with a customer. The traditional electric operating companies and Southern Power also have contracts with multiple performance obligations, such as capacity and energy in a wholesale PPA, 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 registrants recognize revenue as the performance obligations are satisfied over time as electricity or natural gas is delivered to the customer or as generation capacity is available to the customer. At Southern Company Gas, 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. The registrants generally have a right to consideration in an amount that corresponds directly with the value to the customer of the entity's performance completed to date and may recognize revenue in the amount to which the entity has a right to invoice and has elected to recognize revenue for its sales of electricity, capacity, and natural gas using the invoice practical expedient. In addition, payment for goods and services rendered is typically due in the subsequent month following satisfaction of the registrants' performance obligation. The following tables disaggregate revenue sources for the three and nine months ended September 30, 2018 : For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Company Operating revenues Retail electric revenues (a) Residential $ 2,148 $ 5,266 Commercial 1,527 4,084 Industrial 901 2,471 Other 29 92 Natural gas distribution revenues 433 2,299 Alternative revenue programs (b) 5 (23 ) Total retail electric and gas distribution revenues $ 5,043 $ 14,189 Wholesale energy revenues (c)(d) 516 1,444 Wholesale capacity revenues (d) 177 479 Other natural gas revenues (e) 54 530 Other revenues (f) 369 1,516 Total operating revenues $ 6,159 $ 18,158 (a) Retail electric revenues include $17 million and $54 million of leases for the three and nine months ended September 30, 2018 , respectively, and a (net reduction) or net increase of $(98) million and $4 million for the three and nine months ended September 30, 2018 , respectively, from certain cost recovery mechanisms that are not accounted for as revenue under ASC 606. See Note 3 to the financial statements of Southern Company under "Regulatory Matters" in Item 8 of the Form 10-K for additional information on cost recovery mechanisms. (b) See Note 1 to the financial statements of Southern Company under "Revenues" in Item 8 of the Form 10-K for additional information on alternative revenue programs at the natural gas distribution utilities. Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period. (c) Wholesale energy revenues include $63 million and $217 million for the three and nine months ended September 30, 2018 , respectively, of revenues accounted for as derivatives, primarily related to physical energy sales in the wholesale electricity market. See Note (I) for additional information on energy-related derivative contracts. (d) Wholesale energy and wholesale capacity revenues include $130 million and $31 million , respectively, for the three months ended September 30, 2018 and $318 million and $92 million , respectively, for the nine months ended September 30, 2018 of PPA contracts accounted for as leases. (e) Other natural gas revenues related to Southern Company Gas' energy and risk management activities are presented net of the related costs of those activities and include gross third-party revenues of $1.6 billion and $4.8 billion for the three and nine months ended September 30, 2018 , respectively, of which $0.9 billion and $2.7 billion , respectively, relates to contracts that are accounted for as derivatives. See Note (L) under " Southern Company Gas " for additional information on the components of wholesale gas services operating revenues. (f) Other revenues include $92 million and $274 million for the three and nine months ended September 30, 2018 , respectively, of revenues not accounted for under ASC 606. Alabama Power Georgia Power Gulf Power Mississippi Power (in millions) For the Three Months Ended September 30, 2018 Operating revenues Retail revenues (a)(b) Residential $ 721 $ 1,142 $ 200 $ 85 Commercial 464 877 103 82 Industrial 392 385 37 86 Other 7 21 1 1 Total retail electric revenues $ 1,584 $ 2,425 $ 341 $ 254 Wholesale energy revenues (c) 62 33 48 92 Wholesale capacity revenues 26 14 7 1 Other revenues (b)(d) 68 121 18 11 Total operating revenues $ 1,740 $ 2,593 $ 414 $ 358 For the Nine Months Ended September 30, 2018 Operating revenues Retail revenues (a)(b) Residential $ 1,848 $ 2,671 $ 537 $ 209 Commercial 1,238 2,343 291 212 Industrial 1,103 1,036 100 233 Other 19 62 4 6 Total retail electric revenues $ 4,208 $ 6,112 $ 932 $ 660 Wholesale energy revenues (c) 234 99 104 259 Wholesale capacity revenues 75 41 20 6 Other revenues (b)(d) 199 349 50 31 Total operating revenues $ 4,716 $ 6,601 $ 1,106 $ 956 (a) Retail revenues at Alabama Power, Georgia Power, Gulf Power, and Mississippi Power include a net increase or (net reduction) of $(12) million , $(47) million , $(36) million , and $(3) million , respectively, for the three months ended September 30, 2018 and $113 million , $(35) million , $(63) million , and $(11) million , respectively, for the nine months ended September 30, 2018 related to certain cost recovery mechanisms that are not accounted for as revenue under ASC 606. See Note 3 to the financial statements of Alabama Power, Georgia Power, Gulf Power, and Mississippi Power under "Retail Regulatory Matters" in Item 8 of the Form 10-K for additional information on cost recovery mechanisms. (b) Retail revenues and other revenues at Georgia Power include $17 million and $34 million , respectively, for the three months ended September 30, 2018 and $54 million and $100 million , respectively, for the nine months ended September 30, 2018 of revenues accounted for as leases. (c) Wholesale energy revenues at Alabama Power and Georgia Power include $6 million and $8 million , respectively, for the three months ended September 30, 2018 and $14 million and $21 million , respectively, for the nine months ended September 30, 2018 accounted for as derivatives primarily related to physical energy sales in the wholesale electricity market. See Note (I) for additional information on energy-related derivative contracts. (d) Other revenues at Alabama Power, Georgia Power, and Gulf Power include $27 million , $28 million , and $2 million , respectively, for the three months ended September 30, 2018 and $79 million , $80 million , and $5 million , respectively, for the nine months ended September 30, 2018 of revenues not accounted for under ASC 606. For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Power PPA capacity revenues (a) $ 168 $ 450 PPA energy revenues (a) 336 892 Non-PPA revenues (b) 126 347 Other revenues 5 10 Total operating revenues $ 635 $ 1,699 (a) PPA capacity revenues and PPA energy revenues include $47 million and $139 million , respectively, for the three months ended September 30, 2018 and $141 million and $342 million , respectively, for the nine months ended September 30, 2018 related to PPAs accounted for as leases. See Note 1 to the financial statements of Southern Power under "Revenues" in Item 8 of the Form 10-K for additional information on capacity revenues accounted for as leases. (b) Non-PPA revenues include $47 million and $176 million for the three and nine months ended September 30, 2018 , respectively, of revenues from short-term sales related to physical energy sales from uncovered capacity in the wholesale electricity market. See Note 1 to the financial statements of Southern Power under "Revenues" in Item 8 of the Form 10-K and Note (I) for additional information on energy-related derivative contracts. For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Company Gas Operating revenues Natural gas distribution revenues Residential $ 149 $ 1,082 Commercial 45 313 Transportation 203 708 Industrial 4 28 Other 32 168 Alternative revenue programs (a) 5 (23 ) Total natural gas distribution revenues $ 438 $ 2,276 Gas marketing services (b) 44 403 Wholesale gas services (c) (10 ) 121 Gas midstream operations 20 60 Other revenues — 1 Total operating revenues $ 492 $ 2,861 (a) See Note 1 to the financial statements of Southern Company Gas under "Revenues" in Item 8 of the Form 10-K for additional information on alternative revenue programs at the natural gas distribution utilities. Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period. (b) Gas marketing services includes $4 million for the nine months ended September 30, 2018 of revenues not accounted for under ASC 606. (c) Wholesale gas services revenues are presented net of the related costs associated with its energy trading and risk management activities. Operating revenues, as presented, include gross third-party revenues of $1.6 billion and $4.8 billion for the three and nine months ended September 30, 2018 , respectively, of which $0.9 billion and $2.7 billion , respectively, relates to contracts that are accounted for as derivatives. See Note (L) under " Southern Company Gas " for additional information on the components of wholesale gas services operating revenues and Note (I) for additional information on energy-related derivative contracts. Contract Balances The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers as of September 30, 2018 : Receivables Contract Assets Contract Liabilities (in millions) Southern Company $ 2,778 $ 99 $ 34 Alabama Power 649 1 14 Georgia Power 924 70 3 Gulf Power 186 — — Mississippi Power 96 — — Southern Power 142 — 17 Southern Company Gas 523 — 1 As of September 30, 2018 , Alabama Power had contract liabilities for outstanding performance obligations primarily related to extended service agreements. Georgia Power had contract assets primarily related to fixed retail customer bill programs where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over the one-year contract term. Southern Power's contract liabilities relate to collections recognized in advance of revenue for certain levelized PPAs with Georgia Power. Southern Company's unregulated distributed generation business had $27 million and $17 million of contract assets and contract liabilities, respectively, remaining for outstanding performance obligations. Remaining Performance Obligations The traditional electric operating companies and Southern Power have long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. These contracts primarily relate to PPAs whereby the traditional electric operating companies and Southern Power provide electricity and generation capacity 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. 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 September 30, 2018 are expected to be recognized as follows: 2018 2019 2020 2021 2022 2023 and Thereafter (in millions) Southern Company (*) $ 168 $ 406 $ 322 $ 322 $ 310 $ 2,112 Alabama Power 6 22 22 26 23 161 Georgia Power 10 41 38 40 30 113 Gulf Power 5 22 — — — — Mississippi Power 1 3 3 1 — — Southern Power (*) 75 310 283 277 276 2,005 (*) Excludes amounts related to held for sale assets. See Note (J) under " Southern Company's Sale of Gulf Power " and " Southern Power – Sale of Florida Plants " for additional information. |
Fair Value Measurements
Fair Value Measurements | 9 Months Ended |
Sep. 30, 2018 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTS As of September 30, 2018 , 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: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Southern Company Assets: Energy-related derivatives (a)(b) $ 271 $ 150 $ — $ — $ 421 Foreign currency derivatives — 122 — — 122 Nuclear decommissioning trusts (c) 828 1,007 — 37 1,872 Non-qualified deferred compensation trusts: Domestic equity — 11 — — 11 Foreign equity — 6 — — 6 Pooled funds – fixed income — 13 — — 13 Cash equivalents 15 — — — 15 Other 9 — — — 9 Cash equivalents 1,309 — — — 1,309 Total $ 2,432 $ 1,309 $ — $ 37 $ 3,778 Liabilities: Energy-related derivatives (a)(b) $ 416 $ 159 $ — $ — $ 575 Interest rate derivatives — 72 — — 72 Foreign currency derivatives — 23 — — 23 Contingent consideration — — 22 — 22 Total $ 416 $ 254 $ 22 $ — $ 692 Fair Value Measurements Using: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Alabama Power Assets: Energy-related derivatives $ — $ 7 $ — $ — $ 7 Nuclear decommissioning trusts: (d) Domestic equity 469 89 — — 558 Foreign equity 60 56 — — 116 U.S. Treasury and government agency securities — 18 — — 18 Corporate bonds 26 154 — — 180 Mortgage and asset backed securities — 22 — — 22 Private equity — — — 37 37 Other 7 — — — 7 Cash equivalents 513 — — — 513 Total $ 1,075 $ 346 $ — $ 37 $ 1,458 Liabilities: Energy-related derivatives $ — $ 10 $ — $ — $ 10 Georgia Power Assets: Energy-related derivatives $ — $ 8 $ — $ — $ 8 Nuclear decommissioning trusts: (d)(e) Domestic equity 250 1 — — 251 Foreign equity — 134 — — 134 U.S. Treasury and government agency securities — 236 — — 236 Municipal bonds — 82 — — 82 Corporate bonds — 163 — — 163 Mortgage and asset backed securities — 42 — — 42 Other 16 9 — — 25 Cash equivalents 350 — — — 350 Total $ 616 $ 675 $ — $ — $ 1,291 Liabilities: Energy-related derivatives $ — $ 22 $ — $ — $ 22 Interest rate derivatives — 6 — — 6 Total $ — $ 28 $ — $ — $ 28 Gulf Power Assets: Cash equivalents $ 27 $ — $ — $ — $ 27 Liabilities: Energy-related derivatives $ — $ 8 $ — $ — $ 8 Fair Value Measurements Using: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Mississippi Power Assets: Energy-related derivatives $ — $ 3 $ — $ — $ 3 Cash equivalents 346 — — — 346 Total $ 346 $ 3 $ — $ — $ 349 Liabilities: Energy-related derivatives $ — $ 9 $ — $ — $ 9 Southern Power Assets: Energy-related derivatives $ — $ 3 $ — $ — $ 3 Foreign currency derivatives — 122 — — 122 Total $ — $ 125 $ — $ — $ 125 Liabilities: Energy-related derivatives $ — $ 7 $ — $ — $ 7 Foreign currency derivatives — 23 — — 23 Contingent consideration — — 22 — 22 Total $ — $ 30 $ 22 $ — $ 52 Southern Company Gas Assets: Energy-related derivatives (a)(b) $ 271 $ 129 $ — $ — $ 400 Non-qualified deferred compensation trusts: Domestic equity — 11 — — 11 Foreign equity — 6 — — 6 Pooled funds – fixed income — 13 — — 13 Cash equivalents 4 — — — 4 Cash equivalents 26 — — — 26 Total $ 301 $ 159 $ — $ — $ 460 Liabilities: Energy-related derivatives (a)(b) $ 416 $ 101 $ — $ — $ 517 (a) Excludes $5 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value. (b) Excludes cash collateral of $189 million . (c) For additional detail, see the nuclear decommissioning trusts sections for Alabama Power and Georgia Power in this table. (d) Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. (e) Includes the investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. As of September 30, 2018 , approximately $37 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. Southern Company, Alabama Power, and Georgia Power continue to elect the option to fair value investment securities held in the nuclear decommissioning trust funds. The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased for the three and nine months ended September 30, 2018 and 2017 by the amounts shown in the table below. The increases were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively. Three Months Ended September 30, 2018 Three Months Ended September 30, 2017 Nine Months Ended September 30, 2018 Nine Months Ended September 30, 2017 (in millions) Southern Company $ 58 $ 50 $ 68 $ 168 Alabama Power 39 25 49 87 Georgia Power 19 25 19 81 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 (I) 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 1 to the financial statements of Southern Company, Alabama Power, and Georgia Power under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information. Southern Power has contingent payment obligations related to certain acquisitions whereby Southern Power is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation date of the respective facility and continue through 2026. The obligation is categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility 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. "Other investments" include investments that are not traded in the open market. The fair value of these investments has been determined based on market factors including comparable multiples and the expectations regarding cash flows and business plan executions. As of September 30, 2018 , the fair value measurements of private equity investments held in the nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient, as well as the nature and risks of those investments, were as follows: As of September 30, 2018: Fair Value Unfunded Commitments (in millions) Southern Company $ 37 $ 47 Alabama Power $ 37 $ 47 Private equity funds include funds-of-funds that invest in high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a fund that acquires companies to create resale value. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated. Liquidations are expected to occur at various times over the next 10 years . As of September 30, 2018 , other financial instruments for which the carrying amount did not equal fair value were as follows: Carrying Amount Fair Value (in millions) Long-term debt, including securities due within one year: Southern Company $ 45,524 $ 45,500 Alabama Power 8,120 8,321 Georgia Power 10,227 10,159 Gulf Power 1,285 1,290 Mississippi Power 1,736 1,702 Southern Power 5,029 5,058 Southern Company Gas 5,908 5,935 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 Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Southern Power, and Southern Company Gas. |
Stockholders' Equity
Stockholders' Equity | 9 Months Ended |
Sep. 30, 2018 | |
Equity [Abstract] | |
STOCKHOLDERS' EQUITY | STOCKHOLDERS' EQUITY Earnings per Share For Southern Company, the only difference in computing basic and diluted earnings per share is attributable to awards outstanding under stock-based compensation plans. See Note 8 to the financial statements of Southern Company in Item 8 of the Form 10-K for information on stock-based compensation plans. The effect of stock-based compensation plans was determined using the treasury stock method. Shares used to compute diluted earnings per share were as follows: Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended (in millions) As reported shares 1,023 1,003 1,016 998 Effect of stock-based compensation 6 7 5 7 Diluted shares 1,029 1,010 1,021 1,005 Stock-based compensation awards that were not included in the diluted earnings per share calculation because they were anti-dilutive were immaterial for the three and nine months ended September 30, 2018 and 2017 . Changes in Stockholders' Equity The following table presents year-to-date changes in stockholders' equity of Southern Company: Number of Common Shares Common Preferred and Preference Stock of Subsidiaries Total Issued Treasury Noncontrolling Interests (a) (in thousands) (in millions) Balance at December 31, 2017 1,008,532 (929 ) $ 24,167 $ — $ 1,361 $ 25,528 Consolidated net income attributable to Southern Company — — 1,948 — — 1,948 Other comprehensive income — — 52 — — 52 Stock issued 21,342 — 878 — — 878 Stock-based compensation — — 74 — — 74 Cash dividends on common stock — — (1,805 ) — — (1,805 ) Contributions from noncontrolling interests — — — — 154 154 Distributions to noncontrolling interests — — — — (87 ) (87 ) Net income attributable to noncontrolling interests — — — — 71 71 Sale of noncontrolling interests (b) — — (410 ) — 1,690 1,280 Other — (57 ) (27 ) — (1 ) (28 ) Balance at September 30, 2018 1,029,874 (986 ) $ 24,877 $ — $ 3,188 $ 28,065 Balance at December 31, 2016 991,213 (819 ) $ 24,758 $ 609 $ 1,245 $ 26,612 Consolidated net income attributable to Southern Company — — 347 — — 347 Other comprehensive income (loss) — — (2 ) — — (2 ) Stock issued 13,308 — 613 — — 613 Stock-based compensation — — 97 — — 97 Cash dividends on common stock — — (1,716 ) — — (1,716 ) Preference stock redemption — — — (150 ) — (150 ) Contributions from noncontrolling interests — — — — 77 77 Distributions to noncontrolling interests — — — — (87 ) (87 ) Net income attributable to noncontrolling interests — — — — 45 45 Reclassification from redeemable noncontrolling interests — — — — 114 114 Other — (75 ) (15 ) 3 1 (11 ) Balance at September 30, 2017 1,004,521 (894 ) $ 24,082 $ 462 $ 1,395 $ 25,939 (a) Primarily related to Southern Power and excludes redeemable noncontrolling interests. See Note 10 to the financial statements of Southern Power in Item 8 of the Form 10-K for additional information. (b) See Note (J) under "Southern Power – Sale of Solar Facility Interests " for additional information. |
Financing
Financing | 9 Months Ended |
Sep. 30, 2018 | |
Debt Disclosure [Abstract] | |
FINANCING | FINANCING Bank Credit Arrangements Bank credit arrangements provide liquidity support to the registrants' commercial paper borrowings and the traditional electric operating companies' revenue bonds. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support as of September 30, 2018 was approximately $1.5 billion (comprised of approximately $854 million at Alabama Power, $550 million at Georgia Power, $82 million at Gulf Power, and $40 million at Mississippi Power). In addition, at September 30, 2018 , the traditional electric operating companies had approximately $573 million (comprised of approximately $120 million at Alabama Power, $345 million at Georgia Power, $58 million at Gulf Power, and $50 million at Mississippi Power) of revenue bonds outstanding that were required to be remarketed within the next 12 months. Subsequent to September 30, 2018, Alabama Power purchased and held its approximately $120 million of outstanding pollution control revenue bonds required to be remarketed. See Note 6 to the financial statements of each registrant under "Bank Credit Arrangements" in Item 8 of the Form 10-K and " Financing Activities " herein for additional information. The following table outlines the committed credit arrangements by company as of September 30, 2018 : Expires Executable Term Loans Expires Within One Year Company 2018 2019 2020 2022 Total Unused One Year Term Out No Term Out (in millions) Southern Company (a) $ — $ — $ — $ 2,000 $ 2,000 $ 1,999 $ — $ — $ — Alabama Power — 33 500 800 1,333 1,333 — — 33 Georgia Power — — — 1,750 1,750 1,736 — — — Gulf Power 20 25 235 — 280 280 45 45 — Mississippi Power — 100 — — 100 100 — — — Southern Power Company (b) — — — 750 750 728 — — — Southern Company Gas (c) — — — 1,900 1,900 1,895 — — — Other — 30 — — 30 30 — — 30 Southern Company Consolidated $ 20 $ 188 $ 735 $ 7,200 $ 8,143 $ 8,101 $ 45 $ 45 $ 63 (a) Represents the Southern Company parent entity. (b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2019, of which $22 million remains unused at September 30, 2018 . (c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of these arrangements. Southern Company Gas' committed credit arrangements also include $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of 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. DOE Loan Guarantee Borrowings See Note 6 to the financial statements of Southern Company and Georgia Power under "DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for additional information regarding Georgia Power's Loan Guarantee Agreement. On July 27, 2017, Georgia Power entered into an amendment to the Loan Guarantee Agreement (LGA Amendment) in connection with the DOE's consent to Georgia Power's entry into the Vogtle Services Agreement and the related intellectual property licenses (IP Licenses). Under the terms of the Loan Guarantee Agreement, upon termination of the Vogtle 3 and 4 Agreement, further advances are conditioned upon the DOE's approval of any agreements entered into in replacement of the Vogtle 3 and 4 Agreement. Under the terms of the LGA Amendment, Georgia Power will not request any advances unless and until certain conditions are satisfied, including (i) receipt of the DOE's approval of the Bechtel Agreement (together with the Vogtle Services Agreement and the IP Licenses, the Replacement EPC Arrangements) and (ii) Georgia Power's entry into a further amendment to the Loan Guarantee Agreement with the DOE to reflect the Replacement EPC Arrangements. In September 2017, the DOE issued a conditional commitment to Georgia Power for up to approximately $1.67 billion in additional guaranteed loans under the Loan Guarantee Agreement. In September 2018, the DOE extended the conditional commitment to March 31, 2019 . Any further extension must be approved by the DOE. Final approval and issuance of these additional loan guarantees by the DOE cannot be assured and are subject to the negotiation of definitive agreements, completion of due diligence by the DOE, receipt of any necessary regulatory approvals, and satisfaction of other conditions. As of September 30, 2018 , Georgia Power had $2.6 billion of borrowings outstanding under the multi-advance term loan facility (FFB Credit Facility) among Georgia Power, the DOE, and the FFB. Under the 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 (including any decision not to continue construction of Plant Vogtle Units 3 and 4) occur, the FFB's commitment to make further advances under the FFB Credit Facility will terminate and Georgia Power will be required to prepay the outstanding principal amount of all borrowings under the FFB Credit Facility 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 bankruptcy if Georgia Power does not maintain access to intellectual property rights under the IP Licenses; (ii) a decision by Georgia Power not to continue construction of Plant Vogtle Units 3 and 4; (iii) cancellation of Plant Vogtle Units 3 and 4 by the Georgia PSC, or by Georgia Power if authorized by the Georgia PSC; and (iv) cost disallowances by the Georgia PSC that could have a material adverse effect on completion of Plant Vogtle Units 3 and 4 or Georgia Power's ability to repay the outstanding borrowings under the FFB Credit Facility. 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 Facility. In addition, if Georgia Power discontinues construction of Plant Vogtle Units 3 and 4, Georgia Power would be obligated to immediately repay a portion of the outstanding borrowings under the FFB Credit Facility to the extent such outstanding borrowings exceed 70% of Eligible Project Costs, net of the proceeds received by Georgia Power under the Guarantee Settlement Agreement. Georgia Power also may voluntarily prepay outstanding borrowings under the FFB Credit Facility. Under the FFB Credit Facility, any prepayment (whether mandatory or optional) will be made with a make-whole premium or discount, as applicable. Financing Activities The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first nine months of 2018 : Company Senior Note Issuances Senior Note Maturities, Redemptions, and Repurchases Revenue Bond Other Long-Term Debt Issuances Other Long-Term Debt Redemptions and Maturities (a) (in millions) Southern Company (b) $ 750 $ 1,000 $ — $ — $ — Alabama Power 500 — — — — Georgia Power — 1,000 469 — 107 Mississippi Power 600 — 43 — 900 Southern Power — 350 — — 420 Southern Company Gas — — 200 100 — Other — — — — 10 Elimination (c) — — — — (1 ) Southern Company Consolidated $ 1,850 $ 2,350 $ 712 $ 100 $ 1,436 (a) Includes reductions in capital lease obligations resulting from cash payments under capital leases. (b) Represents the Southern Company parent entity. (c) Represents reductions in affiliate capital lease obligations at Georgia Power, which are eliminated in Southern Company's Consolidated Financial Statements. Except as otherwise described herein, Southern Company and its subsidiaries used the proceeds of debt issuances for their redemptions and maturities shown in the table above, to repay short-term indebtedness, and for general corporate purposes, including working capital. The subsidiaries also used the proceeds for their construction programs. Southern Company In March 2018, Southern Company entered into a $900 million short-term floating rate bank loan bearing interest based on one -month LIBOR, which was repaid in August 2018. In April 2018, Southern Company borrowed $250 million pursuant to a short-term uncommitted bank credit arrangement, bearing interest at a rate agreed upon by Southern Company and the bank from time to time and payable on no less than 30 days' demand by the bank. In June 2018, Southern Company repaid at maturity two $100 million short-term floating rate bank term loans. In August 2018, Southern Company issued $750 million aggregate principal amount of Series 2018A Floating Rate Senior Notes due February 14, 2020 bearing interest based on three-month LIBOR, entered into a $1.5 billion short-term floating rate bank loan bearing interest based on one -month LIBOR, and repaid $250 million borrowed in August 2017 pursuant to a short-term uncommitted bank credit arrangement. Alabama Power In June 2018, Alabama Power issued $500 million aggregate principal amount of Series 2018A 4.30% Senior Notes due July 15, 2048. Georgia Power In January 2018, Georgia Power repaid its outstanding $150 million and $100 million floating rate bank loans due May 31, 2018 and October 26, 2018, respectively. In April 2018, Georgia Power redeemed all $250 million aggregate principal amount of its Series 2008B 5.40% Senior Notes due June 1, 2018. In May 2018, through cash tender offers, Georgia Power repurchased and retired $89 million of the $250 million aggregate principal amount outstanding of its Series 2007A 5.65% Senior Notes due March 1, 2037, $326 million of the $500 million aggregate principal amount outstanding of its Series 2009A 5.95% Senior Notes due February 1, 2039, and $335 million of the $600 million aggregate principal amount outstanding of its Series 2010B 5.40% Senior Notes due June 1, 2040, for an aggregate purchase price, excluding accrued and unpaid interest, of $902 million . During 2018, Georgia Power purchased and held the following pollution control revenue bonds, which may be reoffered to the public at a later date: • $104.6 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013 • $173 million aggregate principal amount of Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2009 • $55 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fifth Series 1994 • $65 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008 • $71.735 million aggregate principal amount of Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2013 Mississippi Power In March 2018, Mississippi Power issued $300 million aggregate principal amount of Series 2018A Floating Rate Senior Notes due March 27, 2020 bearing interest based on three -month LIBOR and $300 million aggregate principal amount of Series 2018B 3.95% Senior Notes due March 30, 2028. In March 2018, Mississippi Power also entered into a $300 million short-term floating rate bank loan bearing interest based on one -month LIBOR, of which $200 million was repaid in the second quarter 2018 and $100 million was repaid in the third quarter 2018. Mississippi Power used the proceeds from these financings to repay a $900 million unsecured term loan. In July 2018, Mississippi Power purchased and held approximately $43 million aggregate principal amount of Mississippi Business Finance Corporation Pollution Control Revenue Refunding Bonds, Series 2002. Mississippi Power may reoffer these bonds to the public at a later date. Subsequent to September 30, 2018, Mississippi Power completed the redemption of all 8,867 outstanding shares ( $886,700 aggregate par value) of its 4.40% Series Preferred Stock, all 8,643 outstanding shares ( $864,300 aggregate par value) of its 4.60% Series Preferred Stock, all 16,700 outstanding shares ( $1.67 million aggregate par value) of its 4.72% Series Preferred Stock, all 1,200,000 outstanding depositary shares ( $30 million aggregate stated value) each representing a 1 / 4 th interest in a share of its 5.25% Series Preferred Stock, all $30 million aggregate principal amount outstanding of its Series G 5.40% Senior Notes due July 1, 2035, and all $125 million aggregate principal amount outstanding of its Series 2009A 5.55% Senior Notes due March 1, 2019. Southern Power In May 2018, Southern Power entered into two short-term floating rate bank loans, each for an aggregate principal amount of $100 million , which bear interest based on one -month LIBOR. In the second quarter 2018, Southern Power repaid $420 million aggregate principal amount of long-term floating rate bank loans and $350 million aggregate principal amount of Series 2015A 1.50% Senior Notes due June 1, 2018. During the nine months ended September 30, 2018 , Southern Power received approximately $148 million of third-party tax equity related to the Gaskell West 1 and Cactus Flats facilities. See Note (J) under "Southern Power" for additional information. Southern Company Gas On January 4, 2018, Southern Company Gas issued a floating rate promissory note to Southern Company in an aggregate principal amount of $100 million bearing interest based on one -month LIBOR. On March 28, 2018, Southern Company Gas repaid this promissory note. Prior to its sale, in the second quarter 2018, Pivotal Utility Holdings caused $200 million aggregate principal amount of gas facility revenue bonds to be redeemed. In May 2018, Southern Company Gas Capital borrowed $95 million pursuant to a short-term uncommitted bank credit arrangement, guaranteed by Southern Company Gas, bearing interest at a rate agreed upon by Southern Company Gas Capital and the bank from time to time and payable on no less than 30 days' demand by the bank. The proceeds of the loan were used to repay short-term debt. In July 2018, Southern Company Gas Capital repaid this loan. In July 2018, Nicor Gas agreed to issue $300 million aggregate principal amount of first mortgage bonds in a private placement, $100 million of which was issued in August 2018 and $200 million of which was issued in November 2018. |
Retirement Benefits
Retirement Benefits | 9 Months Ended |
Sep. 30, 2018 | |
Retirement Benefits [Abstract] | |
RETIREMENT BENEFITS | RETIREMENT BENEFITS On January 1, 2018, the qualified defined benefit pension plan of Southern Company Gas was merged into the qualified defined benefit pension plan of Southern Company. Following the plan merger, Southern Company has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The Southern Company qualified defined benefit pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). No mandatory contributions to the Southern Company qualified defined benefit pension plan are anticipated for the year ending December 31, 2018 . In addition, the Southern Company Gas non-qualified retirement plans were merged into the Southern Company non-qualified retirement plan (defined benefit and defined contribution). Following the non-qualified retirement plan mergers, Southern Company continues to provide certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. Furthermore, Southern Company provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund related other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas also provides certain medical care and life insurance benefits for eligible retired employees through a postretirement benefit plan. 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. As indicated in Note (A), the registrants adopted ASU 2017-07 as of January 1, 2018. ASU 2017-07 requires that an employer report the service cost component of net periodic benefit costs in the same line item or items as other compensation costs and requires the other components of net periodic benefit costs to be separately presented in the statements of income outside of income from operations. The presentation requirements of ASU 2017-07 have been applied retrospectively with the service cost component of net periodic benefit costs included in operations and maintenance and all other components of net periodic benefit costs included in other income (expense), net in the statements of income for the three and nine months ended September 30, 2017. With respect to the presentation requirements, the registrants have used the practical expedient provided by ASU 2017-07, which permits an employer to use the amounts disclosed in its retirement benefits footnote for prior comparative periods as the estimation basis for applying the retrospective presentation requirements to those periods. The amounts of the other components of net periodic benefit costs reclassified for the prior period are presented in the following tables. See Note 2 to the financial statements of each registrant in Item 8 of the Form 10-K for additional information. Components of the net periodic benefit costs for the three and nine months ended September 30, 2018 and 2017 are presented in the following tables. Three Months Ended September 30, 2018 Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Power Southern Company Gas (in millions) Pension Plans Service cost $ 90 $ 19 $ 22 $ 4 $ 5 $ 3 $ 8 Interest cost 116 26 34 5 5 1 10 Expected return on plan assets (236 ) (51 ) (74 ) (10 ) (11 ) (3 ) (18 ) Amortization: Prior service costs 1 — 1 — — — (1 ) Regulatory asset — — — — — — 4 Net (gain)/loss 53 13 18 2 3 — 3 Net periodic pension cost (income) $ 24 $ 7 $ 1 $ 1 $ 2 $ 1 $ 6 Postretirement Benefits Service cost $ 6 $ 1 $ 2 $ — $ — $ 1 $ — Interest cost 19 5 7 1 — — 2 Expected return on plan assets (17 ) (7 ) (6 ) — — — (1 ) Amortization: Prior service costs 2 1 — — — — — Regulatory asset — — — — — — 2 Net (gain)/loss 3 — 2 — — — — Net periodic postretirement benefit cost $ 13 $ — $ 5 $ 1 $ — $ 1 $ 3 Nine Months Ended September 30, 2018 Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Power Southern Company Gas (in millions) Pension Plans Service cost $ 269 $ 58 $ 65 $ 12 $ 13 $ 7 $ 24 Interest cost 348 76 104 15 15 4 29 Expected return on plan assets (707 ) (155 ) (222 ) (30 ) (31 ) (8 ) (53 ) Amortization: Prior service costs 3 1 2 — — — (2 ) Regulatory asset — — — — — — 11 Net (gain)/loss 160 40 52 7 8 1 9 Net periodic pension cost (income) $ 73 $ 20 $ 1 $ 4 $ 5 $ 4 $ 18 Postretirement Benefits Service cost $ 18 $ 4 $ 5 $ 1 $ 1 $ 1 $ 1 Interest cost 56 13 21 2 2 — 7 Expected return on plan assets (51 ) (20 ) (19 ) (1 ) (1 ) — (5 ) Amortization: Prior service costs 5 3 1 — — — — Regulatory asset — — — — — — 5 Net (gain)/loss 10 1 6 — — — — Net periodic postretirement benefit cost $ 38 $ 1 $ 14 $ 2 $ 2 $ 1 $ 8 Three Months Ended September 30, 2017 (*) Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (in millions) Pension Plans Service cost $ 73 $ 15 $ 19 $ 3 $ 4 $ 6 Interest cost 114 25 34 5 5 10 Expected return on plan assets (224 ) (49 ) (71 ) (10 ) (9 ) (18 ) Amortization: Prior service costs 3 1 — — — — Net (gain)/loss 41 10 15 2 1 5 Net periodic pension cost (income) $ 7 $ 2 $ (3 ) $ — $ 1 $ 3 Postretirement Benefits Service cost $ 6 $ 1 $ 2 $ — $ — $ 1 Interest cost 19 4 6 1 1 3 Expected return on plan assets (16 ) (5 ) (6 ) — — (2 ) Amortization: Prior service costs 2 1 — — — (1 ) Net (gain)/loss 3 — 3 — — 1 Net periodic postretirement benefit cost $ 14 $ 1 $ 5 $ 1 $ 1 $ 2 (*) Excludes Southern Power since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017. Nine Months Ended September 30, 2017 (*) Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (in millions) Pension Plans Service cost $ 220 $ 47 $ 56 $ 10 $ 11 $ 17 Interest cost 341 73 103 15 15 30 Expected return on plan assets (673 ) (147 ) (212 ) (29 ) (29 ) (53 ) Amortization: Prior service costs 9 2 2 — 1 (1 ) Net (gain)/loss 122 31 43 5 5 15 Net periodic pension cost (income) $ 19 $ 6 $ (8 ) $ 1 $ 3 $ 8 Postretirement Benefits Service cost $ 18 $ 4 $ 5 $ 1 $ 1 $ 2 Interest cost 59 13 21 2 3 8 Expected return on plan assets (49 ) (19 ) (18 ) (1 ) (1 ) (5 ) Amortization: Prior service costs 5 3 1 — — (2 ) Net (gain)/loss 10 1 6 — — 3 Net periodic postretirement benefit cost $ 43 $ 2 $ 15 $ 2 $ 3 $ 6 (*) Excludes Southern Power since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017. |
Income Taxes
Income Taxes | 9 Months Ended |
Sep. 30, 2018 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | INCOME TAXES See Note 5 to the financial statements of each registrant in Item 8 of the Form 10-K for additional tax information. Federal Tax Reform Legislation Following the enactment of the Tax Reform Legislation, the SEC staff issued Staff Accounting Bulletin 118 – "Income Tax Accounting Implications of the Tax Cuts and Jobs Act" (SAB 118), which provides for a measurement period of up to one year from the enactment date to complete accounting under GAAP for the tax effects of the legislation. Due to the complex and comprehensive nature of the enacted tax law changes, and their application under GAAP, the registrants consider all amounts recorded in the financial statements as a result of the Tax Reform Legislation to be "provisional" as discussed in SAB 118 and subject to revision. Each of the registrants is awaiting additional guidance from industry and income tax authorities in order to finalize its accounting. The ultimate impact of the Tax Reform Legislation on deferred income tax assets and liabilities and the related regulatory assets and liabilities cannot be determined at this time. See Note (B) under " Regulatory Matters " for additional information. Current and Deferred Income Taxes Tax Credit Carryforwards Southern Company had federal ITC and PTC carryforwards (primarily related to Southern Power) totaling $2.4 billion as of September 30, 2018 compared to $2.1 billion as of December 31, 2017 . The federal ITC and PTC carryforwards begin expiring in 2034 and 2032, respectively, but are expected to be fully utilized by 2023. The estimated tax credit utilization reflects the 2018 abandonment loss related to certain Kemper County energy facility expenditures as well as the projected taxable gains on the various sale transactions described in Note (J) and " Legal Entity Reorganizations " herein. The expected utilization of tax credit carryforwards could be further delayed by numerous factors, including the acquisition of additional renewable projects, increased generation at existing wind facilities, the purchase of rights to additional PTCs during construction of Plant Vogtle Units 3 and 4 pursuant to the MEAG Term Sheet, and changes in taxable income projections. See Note (B) under "Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4. The ultimate outcome of these matters cannot be determined at this time. Valuation Allowances Georgia Power Mississippi Power Southern Company Gas Southern Company (in millions) Federal $ 6 $ — $ 11 $ 19 State (net of federal benefit) 33 124 1 171 Balance at September 30, 2018 $ 39 $ 124 $ 12 $ 190 Southern Company had valuation allowances, net of related federal benefits, of $ 190 million at September 30, 2018 compared to $ 148 million at December 31, 2017. The increase was primarily due to Georgia Power's projected inability to utilize certain state tax credit carryforwards. Effective Tax Rate Each registrant's effective tax rate for the nine months ended September 30, 2018 varied significantly as compared to the corresponding period in 2017 due to the 14% lower 2018 federal tax rate resulting from the Tax Reform Legislation. Southern Company Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity, and federal income tax benefits from ITCs and PTCs. Southern Company's effective tax rate was 22.7% for the nine months ended September 30, 2018 compared to 42.6% for the corresponding period in 2017 . The effective tax rate decrease was primarily due to the reduction in the federal corporate income tax rate and the benefit from the flowback of excess deferred income taxes as a result of the Tax Reform Legislation, the net state income tax benefits related to changes in state apportionment rates arising from the reorganization of Southern Power's legal entities as discussed further herein, and the $3.1 billion pre-tax loss on the Kemper IGCC, net of the non-deductible AFUDC equity portion, recorded in 2017, partially offset by the $1.1 billion pre-tax loss related to Plant Vogtle Units 3 and 4 and the income taxes recorded related to the Southern Company Gas Dispositions in 2018. See Note 3 to the financial statements of Southern Company under "Kemper County Energy Facility" in Item 8 of the Form 10-K and Note (B) under " Kemper County Energy Facility " for additional information regarding the Kemper IGCC and Note (B) under " Nuclear Construction " for additional information regarding Plant Vogtle Units 3 and 4. See Note (B) under "Regulatory Matters" for additional information on the flowback of excess deferred income taxes and Note (J) under "Southern Company Gas" for additional information on the Southern Company Gas Dispositions. Southern Company recognizes PTCs when wind energy is generated and sold (using the prescribed KWH rate in applicable federal and state statutes), which may differ significantly from amounts computed on a quarterly basis using an overall estimated annual effective income tax rate. Southern Company uses this method of recognition since the amount of PTCs can be significantly impacted by wind generation. This method can significantly affect the effective income tax rate for the period depending on the amount of pretax income. Alabama Power Alabama Power's effective tax rate was 23.9% for the nine months ended September 30, 2018 compared to 39.9% for the corresponding period in 2017 . The effective tax rate decrease was primarily due to the reduction in the federal corporate income tax rate and the benefit from the flowback of excess deferred income taxes as a result of the Tax Reform Legislation. See Note (B) under "Regulatory Matters – Alabama Power" for additional information. Georgia Power Georgia Power's effective tax rate was 25.5% for the nine months ended September 30, 2018 compared to 37.0% for the corresponding period in 2017 . The effective tax rate decrease was primarily due to the reduction in the federal corporate income tax rate and the $1.1 billion pre-tax loss related to the estimated probable loss on Plant Vogtle Units 3 and 4 recorded in 2018, partially offset by the valuation allowance on certain state tax credit carryforwards. See Note (B) under " Nuclear Construction " for additional information. Gulf Power Gulf Power's effective tax benefit rate was (0.5)% for the nine months ended September 30, 2018 compared to an effective tax rate of 39.4% for the corresponding period in 2017 . The effective tax rate decrease was primarily due to the reduction in the federal corporate income tax rate and the benefit from the flowback of excess deferred income taxes as a result of the Tax Reform Legislation. See Note (B) under "Regulatory Matters – Gulf Power" for additional information. Mississippi Power Mississippi Power's effective tax rate was 20.8% for the nine months ended September 30, 2018 compared to a benefit rate of (30.3)% for the corresponding period in 2017 . The effective tax rate increase was primarily due to the $3.1 billion pre-tax loss on the Kemper IGCC, net of the non-deductible AFUDC equity portion, recorded in 2017, partially offset by the reduction in the federal corporate income tax rate as a result of the Tax Reform Legislation. See Note (B) under "Regulatory Matters – Mississippi Power" for additional information. Southern Power Southern Power's effective tax benefit rate was (220.3)% for the nine months ended September 30, 2018 compared to (66.5)% for the corresponding period in 2017 . The effective tax rate decrease was primarily due to lower earnings before income taxes resulting from a $119 million asset impairment charge as a result of the pending sale of Plant Oleander and Plant Stanton Unit A (together, the Florida Plants) and a $36 million asset impairment charge on wind turbine equipment held for development projects, as well as the reduction in the federal corporate income tax rate and the net state income tax benefits related to certain changes in apportionment rates arising from the reorganization of Southern Power's legal entities as described below. See Note (J) under "Southern Power" for additional information. Southern Power recognizes PTCs when wind energy is generated and sold (using the prescribed KWH rate in applicable federal and state statutes), which may differ significantly from amounts computed on a quarterly basis using an overall estimated annual effective income tax rate. Southern Power uses this method of recognition since the amount of PTCs can be significantly impacted by wind generation. This method can significantly affect the effective income tax rate for the period depending on the amount of pretax income. Southern Company Gas Southern Company Gas' effective tax rate was 61.8% for the nine months ended September 30, 2018 compared to 43.4% for the corresponding period in 2017 . This increase was primarily related to income taxes recorded related to the Southern Company Gas Dispositions, partially offset by the reduction in the federal corporate income tax rate and the benefit from the flowback of excess deferred income taxes as a result of the Tax Reform Legislation, as well as the 2017 increases in deferred tax expense related to the enactment of the State of Illinois income tax legislation and new income tax apportionment factors in several states. See Note (B) under "Regulatory Matters – Southern Company Gas" and Note (J) under "Southern Company Gas" for additional information. Legal Entity Reorganizations In April 2018, Southern Power completed the final stage of a legal entity reorganization of various direct and indirect subsidiaries that own and operate substantially all of its solar facilities, including certain subsidiaries owned in partnership with various third parties. The reorganization resulted in net state tax benefits related to certain changes in apportionment rates totaling approximately $54 million , which were recorded in the first half of 2018. In September 2018, Southern Power also completed a legal reorganization of eight operating wind facilities under a new holding company, SP Wind, which resulted in net state tax benefits totaling approximately $11 million related to certain changes in apportionment rates. Unrecognized Tax Benefits See Note 5 to the financial statements of each registrant under "Unrecognized Tax Benefits" in Item 8 of the Form 10-K for additional information. The registrants had no unrecognized tax benefits as of September 30, 2018 . It is reasonably possible that the amount of the unrecognized tax benefits could change within 12 months . The settlement of federal and state audits could impact the balances significantly. At this time, an estimate of the range of reasonably possible outcomes cannot be determined. The IRS has finalized its audits of Southern Company's consolidated income tax returns through 2016, as well as the pre-Merger Southern Company Gas tax returns. Southern Company is a participant in the Compliance Assurance Process of the IRS. The audits for Southern Company's state income tax returns have either been concluded, or the statute of limitations has expired, for years prior to 2012. |
Derivatives
Derivatives | 9 Months Ended |
Sep. 30, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
DERIVATIVES | DERIVATIVES Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company Gas' wholesale gas operations use various contracts in its commercial activities that generally meet the definition of derivatives. 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 (D) for additional information. In the statements of cash flows, the cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. The cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with classification of the hedged interest or principal, respectively. The registrants adopted ASU 2017-12 as of January 1, 2018. See Note (A) under " Recently Adopted Accounting Standards – Other " for additional information. Energy-Related Derivatives Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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 is expected to continue to mitigate price volatility. The Florida PSC approved a moratorium on Gulf Power's fuel-hedging program until January 1, 2021. The moratorium does not have an impact on the recovery of existing hedges entered into under the previously-approved hedging program. 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 of operating margins 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 which are 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 the respective fuel cost recovery clauses. • 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 OCI 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 September 30, 2018 , the net volume of energy-related derivative contracts for natural gas positions for the Southern Company system, 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 (*) 595 2022 2029 Alabama Power 82 2022 — Georgia Power 165 2022 — Gulf Power 9 2020 — Mississippi Power 69 2022 — Southern Power 15 2020 — Southern Company Gas (*) 255 2021 2029 (*) Southern Company's and 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 4.3 billion mmBtu and short natural gas positions of 4 billion mmBtu as of September 30, 2018 , 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 gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 13 million mmBtu for Southern Company, 2 million mmBtu for Alabama Power, 4 million mmBtu for Georgia Power, 1 million mmBtu for Gulf Power, 2 million mmBtu for Mississippi Power, and 4 million mmBtu for Southern Power. For cash flow hedges of energy-related derivatives, the amounts expected to be reclassified from accumulated OCI to earnings for the next 12 -month period ending September 30, 2019 are immaterial for all registrants. Interest Rate Derivatives Southern Company and certain subsidiaries may also enter into interest rate derivatives to hedge exposure to changes in interest rates. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. 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 September 30, 2018 , the following interest rate derivatives were outstanding: Notional Amount Interest Rate Received Weighted Average Interest Rate Paid Hedge Maturity Date Fair Value Gain (Loss) at September 30, 2018 (in millions) (in millions) Fair Value Hedges of Existing Debt Southern Company (*) $ 300 2.75% 3-month June 2020 $ (6 ) Southern Company (*) 1,500 2.35% 1-month July 2021 (60 ) Georgia Power 500 1.95% 3-month December 2018 (3 ) Georgia Power 200 4.25% 3-month December 2019 (3 ) Southern Company Consolidated $ 2,500 $ (72 ) (*) Represents the Southern Company parent entity. The estimated pre-tax gains (losses) related to interest rate derivatives expected to be reclassified from accumulated OCI to interest expense for the next 12 -month period ending September 30, 2019 are $(19) million for Southern Company and immaterial for all other registrants. Southern Company and certain subsidiaries have deferred gains and losses expected to be amortized into earnings through 2046 . Foreign Currency Derivatives Southern Company and certain subsidiaries may also 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. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. At September 30, 2018 , the following foreign currency derivatives were outstanding: Pay Notional Pay Rate Receive Notional Receive Rate Hedge Fair Value Gain (Loss) at September 30, 2018 (in millions) (in millions) (in millions) Cash Flow Hedges of Existing Debt Southern Power $ 677 2.95% € 600 1.00% June 2022 $ 48 Southern Power 564 3.78% 500 1.85% June 2026 51 Total $ 1,241 € 1,100 $ 99 The estimated pre-tax gains (losses) related to foreign currency derivatives that will be reclassified from accumulated OCI to earnings for the next 12 -month period ending September 30, 2019 are $(23) million for Southern Company and Southern Power. Derivative Financial Statement Presentation and Amounts Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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 sheet 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: As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Southern Company Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 15 $ 17 $ 10 $ 43 Other deferred charges and assets/Other deferred credits and liabilities 5 26 7 24 Assets held for sale, current/Liabilities held for sale, current — 6 — — Assets held for sale/Liabilities held for sale — 2 — — Total derivatives designated as hedging instruments for regulatory purposes $ 20 $ 51 $ 17 $ 67 Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Other current assets/Other current liabilities $ 3 $ 6 $ 3 $ 14 Other deferred charges and assets/Other deferred credits and liabilities 1 1 — — Interest rate derivatives: Other current assets/Other current liabilities — 22 1 4 Other deferred charges and assets/Other deferred credits and liabilities — 50 — 34 Foreign currency derivatives: Other current assets/Other current liabilities — 23 — 23 Other deferred charges and assets/Other deferred credits and liabilities 122 — 129 — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ 126 $ 102 $ 133 $ 75 Derivatives not designated as hedging instruments Energy-related derivatives: Other current assets/Other current liabilities $ 263 $ 317 $ 380 $ 437 Other deferred charges and assets/Other deferred credits and liabilities 134 198 170 215 Total derivatives not designated as hedging instruments $ 397 $ 515 $ 550 $ 652 Gross amounts recognized $ 543 $ 668 $ 700 $ 794 Gross amounts offset (a) $ (303 ) $ (491 ) $ (405 ) $ (598 ) Net amounts recognized in the Balance Sheets (b) $ 240 $ 177 $ 295 $ 196 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Alabama Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 5 $ 4 $ 2 $ 6 Other deferred charges and assets/Other deferred credits and liabilities 2 6 2 4 Total derivatives designated as hedging instruments for regulatory purposes $ 7 $ 10 $ 4 $ 10 Gross amounts recognized $ 7 $ 10 $ 4 $ 10 Gross amounts offset $ (4 ) $ (4 ) $ (4 ) $ (4 ) Net amounts recognized in the Balance Sheets $ 3 $ 6 $ — $ 6 Georgia Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 5 $ 9 $ 2 $ 9 Other deferred charges and assets/Other deferred credits and liabilities 2 13 4 10 Total derivatives designated as hedging instruments for regulatory purposes $ 7 $ 22 $ 6 $ 19 Derivatives designated as hedging instruments in cash flow and fair value hedges Interest rate derivatives: Other current assets/Other current liabilities $ — $ 5 $ — $ 4 Other deferred charges and assets/Other deferred credits and liabilities — 1 — 1 Total derivatives designated as hedging instruments in cash flow and fair value hedges $ — $ 6 $ — $ 5 Gross amounts recognized $ 7 $ 28 $ 6 $ 24 Gross amounts offset $ (7 ) $ (7 ) $ (6 ) $ (6 ) Net amounts recognized in the Balance Sheets $ — $ 21 $ — $ 18 Gulf Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ — $ 6 $ — $ 14 Other deferred charges and assets/Other deferred credits and liabilities — 2 — 7 Total derivatives designated as hedging instruments for regulatory purposes $ — $ 8 $ — $ 21 Gross amounts recognized $ — $ 8 $ — $ 21 Net amounts recognized in the Balance Sheets $ — $ 8 $ — $ 21 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Mississippi Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 2 $ 3 $ 1 $ 6 Other deferred charges and assets/Other deferred credits and liabilities 1 6 1 3 Total derivatives designated as hedging instruments for regulatory purposes $ 3 $ 9 $ 2 $ 9 Derivatives designated as hedging instruments in cash flow and fair value hedges Interest rate derivatives: Other current assets/Other current liabilities $ — $ — $ 1 $ — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ — $ — $ 1 $ — Gross amounts recognized $ 3 $ 9 $ 3 $ 9 Gross amounts offset $ (3 ) $ (3 ) $ (2 ) $ (2 ) Net amounts recognized in the Balance Sheets $ — $ 6 $ 1 $ 7 Southern Power Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Other current assets/Other current liabilities $ 2 $ 6 $ 3 $ 11 Other deferred charges and assets/Other deferred credits and liabilities 1 1 — — Foreign currency derivatives: Other current assets/Other current liabilities — 23 — 23 Other deferred charges and assets/Other deferred credits and liabilities 122 — 129 — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ 125 $ 30 $ 132 $ 34 Derivatives not designated as hedging instruments Energy-related derivatives: Other current assets/Other current liabilities $ — $ — $ — $ 2 Gross amounts recognized $ 125 $ 30 $ 132 $ 36 Gross amounts offset $ (2 ) $ (2 ) $ (3 ) $ (3 ) Net amounts recognized in the Balance Sheets $ 123 $ 28 $ 129 $ 33 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Southern Company Gas Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Assets from risk management activities/Liabilities from risk management activities-current $ 3 $ 1 $ 5 $ 8 Other deferred charges and assets/Other deferred credits and liabilities — 1 — — Total derivatives designated as hedging instruments for regulatory purposes $ 3 $ 2 $ 5 $ 8 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-current $ 1 $ — $ — $ 3 Derivatives not designated as hedging instruments Energy-related derivatives: Assets from risk management activities/Liabilities from risk management activities-current $ 262 $ 316 $ 379 $ 434 Other deferred charges and assets/Other deferred credits and liabilities 134 198 170 215 Total derivatives not designated as hedging instruments $ 396 $ 514 $ 549 $ 649 Gross amounts of recognized $ 400 $ 516 $ 554 $ 660 Gross amounts offset (a) $ (287 ) $ (475 ) $ (390 ) $ (583 ) Net amounts recognized in the Balance Sheets (b) $ 113 $ 41 $ 164 $ 77 (a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $189 million and $193 million as of September 30, 2018 and December 31, 2017 , respectively. (b) Net amounts of derivative instruments outstanding exclude premium and intrinsic value associated with weather derivatives of $5 million and $11 million as of September 30, 2018 and December 31, 2017 , respectively. At September 30, 2018 and December 31, 2017 , 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 Sheet at September 30, 2018 Derivative Category and Balance Sheet Location Southern Company (*) Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (*) (in millions) Energy-related derivatives: Other regulatory assets, current $ (9 ) $ (2 ) $ (4 ) $ (6 ) $ (2 ) $ (1 ) Other regulatory assets, deferred (20 ) (4 ) (11 ) (2 ) (5 ) — Assets held for sale, current (6 ) — — — — — Assets held for sale (2 ) — — — — — Other regulatory liabilities, current 8 3 — — — 5 Total energy-related derivative gains (losses) $ (29 ) $ (3 ) $ (15 ) $ (8 ) $ (7 ) $ 4 (*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $3 million at September 30, 2018 . Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet at December 31, 2017 Derivative Category and Balance Sheet Location Southern Company (*) Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (*) (in millions) Energy-related derivatives: Other regulatory assets, current $ (34 ) $ (4 ) $ (7 ) $ (14 ) $ (5 ) $ (4 ) Other regulatory assets, deferred (18 ) (3 ) (6 ) (7 ) (2 ) — Other regulatory liabilities, current 7 — — — — 7 Other regulatory liabilities, deferred 1 1 — — — — Total energy-related derivative gains (losses) $ (44 ) $ (6 ) $ (13 ) $ (21 ) $ (7 ) $ 3 (*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $6 million at December 31, 2017 . For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of cash flow hedge accounting on accumulated OCI were as follows: Gain (Loss) Recognized in OCI on Derivative For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Company Energy-related derivatives $ (5 ) $ (6 ) $ 7 $ (26 ) Interest rate derivatives — (1 ) (2 ) (2 ) Foreign currency derivatives (10 ) 46 (31 ) 114 Total $ (15 ) $ 39 $ (26 ) $ 86 Southern Power Energy-related derivatives $ (5 ) $ (6 ) $ 5 $ (21 ) Foreign currency derivatives (10 ) 46 (31 ) 114 Total $ (15 ) $ 40 $ (26 ) $ 93 Southern Company Gas Energy-related derivatives $ — $ — $ 2 $ (4 ) For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of energy-related derivatives and interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other registrants. For the three and nine months ended September 30, 2017 , there was no material ineffectiveness recorded in earnings for any registrant. Upon the adoption of ASU 2017-12, beginning in 2018, ineffectiveness was no longer separately measured and recorded in earnings. See Note (A) for additional information. For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of cash flow and fair value hedge accounting on income were as follows: Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Company Cost of natural gas $ 104 $ 134 $ 1,053 $ 1,085 Gain (loss) on cash flow hedges (a) Energy-related derivatives — — (2 ) — Depreciation and amortization 787 767 2,338 2,236 Gain (loss) on cash flow hedges (a) Energy-related derivatives — (6 ) 2 (12 ) Interest expense, net of amounts capitalized (458 ) (407 ) (1,386 ) (1,248 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (5 ) (5 ) (16 ) (15 ) Foreign currency derivatives (6 ) (5 ) (18 ) (17 ) Gain (loss) on fair value hedges (b) Interest rate derivatives (4 ) (5 ) (35 ) (6 ) Other income (expense), net 57 65 195 165 Gain (loss) on cash flow hedges (a)(c) Foreign currency derivatives (9 ) 43 (46 ) 139 Alabama Power Interest expense, net of amounts capitalized $ (82 ) $ (76 ) $ (240 ) $ (229 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (1 ) (2 ) (4 ) (5 ) Georgia Power Interest expense, net of amounts capitalized $ (95 ) $ (105 ) $ (303 ) $ (310 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (1 ) (1 ) (4 ) (3 ) Gain (loss) on fair value hedges (b) Interest rate derivatives — — (1 ) (1 ) Mississippi Power Interest expense, net of amounts capitalized $ (19 ) $ 13 $ (59 ) $ (23 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives — — (1 ) (1 ) Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Power Depreciation and amortization $ 130 $ 131 $ 370 $ 379 Gain (loss) on cash flow hedges (a) Energy-related derivatives — (6 ) 2 (12 ) Interest expense, net of amounts capitalized (45 ) (47 ) (138 ) (144 ) Gain (loss) on cash flow hedges (a) Foreign currency derivatives (6 ) (5 ) (18 ) (17 ) Other income (expense), net 17 3 22 3 Gain (loss) on cash flow hedges (a)(c) Foreign currency derivatives (9 ) 43 (46 ) 139 Southern Company Gas Cost of natural gas $ 104 $ 134 $ 1,053 $ 1,085 Gain (loss) on cash flow hedges (a) Energy-related derivatives — — (2 ) — (a) Amounts reflect gains or losses on cash flow hedges that were reclassified from accumulated OCI into income. (b) For fair value hedges presented above, generally changes in the fair value of the derivative contracts are equal to changes in the fair value of the underlying debt and have no material impact on income. (c) The reclassification from accumulated OCI 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. For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of cash flow hedge accounting on income for interest rate derivatives were immaterial for Gulf Power and Southern Company Gas. As of September 30, 2018 and December 31, 2017, 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 As of September 30, 2018 As of December 31, 2017 As of September 30, 2018 As of December 31, 2017 (in millions) (in millions) Southern Company Securities due within one year $ (499 ) $ (746 ) $ 1 $ 3 Long-term debt (2,526 ) (2,553 ) 65 35 Georgia Power Securities due within one year $ (499 ) $ (746 ) $ 1 $ 3 Long-term debt (497 ) (498 ) 2 1 For the three and nine months ended September 30, 2018 and 2017 , 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 were as follows: Gain (Loss) Three Months Ended September 30, Nine Months Ended Derivatives in Non-Designated Hedging Relationships Statements of Income Location 2018 2017 2018 2017 (in millions) (in millions) Energy-related derivatives: Natural gas revenues (*) $ (36 ) $ (17 ) $ (79 ) $ 48 Cost of natural gas 2 2 5 (2 ) Total derivatives in non-designated hedging relationships $ (34 ) $ (15 ) $ (74 ) $ 46 (*) Excludes gains (losses) recorded in natural gas revenues associated with weather derivatives of $15 million for the nine months ended September 30, 2017 and immaterial amounts for all other periods presented. For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of energy-related derivatives and interest rate derivatives not designated as hedging instruments were immaterial f or the traditional electric operating companies and Southern Power. Contingent Features Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. At September 30, 2018 , the registrants had no collateral posted with derivative counterparties to satisfy these arrangements. For the registrants with interest rate derivatives at September 30, 2018 , the fair value of 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 immaterial. At September 30, 2018 , the fair value of 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 for all registrants. 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. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts recognized for derivatives executed with the same counterparty. Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Alabama Power and Southern Power may be required to post collateral. At September 30, 2018 , cash collateral posted in these accounts was immaterial. 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 September 30, 2018 , cash collateral held on deposit in broker margin accounts was $189 million . Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas are exposed to losses related to financial instruments in the event of counterparties' nonperformance. Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate Southern Company's, the traditional electric operating companies', Southern Power's, and Southern Company Gas' exposure to counterparty credit risk. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary. In addition, Southern Company Gas conducts credit evaluations and obtains appropriate internal approvals for the counterparty's line of credit before any transaction with the counterparty is executed. In most cases, the counterparty must have an investment grade rating, which includes a minimum long-term debt rating of Baa3 from Moody's and BBB- from S&P. Generally, Southern Company Gas requires credit enhancements by way of a guaranty, cash deposit, or letter of credit for transaction counterparties that do not have investment grade ratings. Southern Company Gas also utilizes master netting agreements whenever possible to mitigate exposure to counterparty credit risk. When Southern Company Gas is engaged in more than one outstanding derivative transaction with the same counterparty and it also has a legally enforceable netting agreement with that counterparty, the "net" mark-to-market exposure represents the netting of the positive and negative exposures with that counterparty and a reasonable measure of Southern Company Gas' credit risk. Southern Company Gas also uses other netting agreements with certain counterparties with whom it conducts significant transactions. Master netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty. Southern Company Gas also nets across product lines and against cash collateral provided the master netting and cash collateral agreements include such provisions. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary. Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas do not anticipate a ma |
Acquisitions and Dispositions
Acquisitions and Dispositions | 9 Months Ended |
Sep. 30, 2018 | |
Business Combinations [Abstract] | |
ACQUISITIONS AND DISPOSITIONS | ACQUISITIONS AND DISPOSITIONS Southern Company's Sale of Gulf Power On May 20, 2018, Southern Company entered into a stock purchase agreement (Gulf Power SPA) with NextEra Energy and its wholly-owned subsidiary 700 Universe, LLC, which provides for the sale of all of the capital stock of Gulf Power for an aggregate cash purchase price of $5.75 billion (less the amount of indebtedness assumed at closing, which is currently estimated at approximately $1.3 billion ), subject to (i) customary adjustments for indebtedness and working capital and (ii) reduction by the amount (if any) by which Gulf Power fails to meet a specified capital expenditure target. The Gulf Power SPA contains customary representations, warranties, and covenants of Southern Company, 700 Universe, LLC, and NextEra Energy. These covenants include, among others, an obligation of Southern Company to cause Gulf Power to operate its business in the ordinary course until the sale is consummated and an obligation for each of the parties to use reasonable best efforts to obtain the governmental and regulatory approvals described below. The completion of the sale is subject to the satisfaction or waiver of certain closing conditions, including, among others, (i) approval by the FERC and the Federal Communications Commission, (ii) the entry into certain ancillary agreements, including transmission-related agreements and a transition services agreement, among the parties and their affiliates, and (iii) other customary closing conditions. The Gulf Power SPA may be terminated by either Southern Company or 700 Universe, LLC under certain circumstances, including if the sale is not consummated by June 28, 2019 (subject to extension to December 31, 2019, if all of the conditions to closing, other than the conditions related to obtaining regulatory approvals, have been satisfied). The Gulf Power SPA further provides that, upon the termination thereof, (i) under certain specified circumstances, 700 Universe, LLC will be required to pay Southern Company a termination fee of $100 million or $200 million (such amount depending on the specific circumstances of such termination) and (ii) upon certain other specified circumstances Southern Company will be required to pay 700 Universe, LLC a termination fee of $100 million . The sale of Gulf Power is expected to occur in the first quarter 2019. The assets and liabilities of Gulf Power are classified as assets held for sale and liabilities held for sale on Southern Company's balance sheet as of September 30, 2018 . See " Assets Held for Sale " below for additional information. The ultimate outcome of this matter cannot be determined at this time. Southern Power See Note 11 to the financial statements of Southern Power and Note 12 to the financial statements of Southern Company under "Southern Power" in Item 8 of the Form 10-K for additional information. Acquisitions During the Nine Months Ended September 30, 2018 During the nine months ended September 30, 2018, one of Southern Power's wholly-owned subsidiaries acquired and completed construction of the Gaskell West 1 solar facility . Acquisition-related costs were expensed as incurred and were not material. Project Facility Resource Seller; Acquisition Date Approximate Nameplate Capacity ( MW ) Location Southern Power Percentage Ownership Actual COD PPA Contract Period Gaskell West 1 Solar Recurrent Energy Development Holdings, LLC January 26, 2018 20 Kern County, CA 100% of Class B (*) March 2018 20 years (*) Southern Power owns 100% of the class B membership interests under a tax equity partnership agreement. The Gaskell West 1 facility did not have operating revenues or activities prior to completion of construction and the assets being placed in service during March 2018. Construction Projects in Progress and/or Completed During the nine months ended September 30, 2018 , Southern Power started, continued, or completed construction of the projects set forth in the table below. Total aggregate construction costs, excluding the acquisition costs, are expected to be between $575 million and $640 million for the Mankato, Wild Horse Mountain, and Reading facilities. At September 30, 2018 , construction costs included in CWIP related to these projects totaled $246 million . The ultimate outcome of these matters cannot be determined at this time. Project Facility Resource Approximate Nameplate Capacity ( MW ) Location Actual/Expected COD PPA Contract Period Cactus Flats (a) Wind 148 Concho County, TX July 2018 12-15 years Mankato Natural Gas 385 Mankato, MN First half 2019 20 years Wild Horse Mountain (b) Wind 100 Pushmataha County, OK Fourth quarter 2019 20 years Reading (c) Wind 200 Osage and Lyon Counties, KS Second quarter 2020 12 years (a) In July 2017, Southern Power purchased 100% of the Cactus Flats facility and commenced construction. In July 2018, the facility was placed in service and, in August 2018, Southern Power closed on a tax equity partnership agreement and owns 100% of the class B membership interests. (b) In May 2018, Southern Power purchased 100% of the Wild Horse Mountain facility and commenced construction. Southern Power may enter into a tax equity partnership agreement, in which case it would then own 100% of the class B membership interests. (c) In August 2018, Southern Power purchased 100% of the membership interests from the joint development arrangement with Renewable Energy Systems Americas, Inc. and commenced construction. Southern Power may enter into a tax equity partnership agreement, in which case it would then own 100% of the class B membership interests. Development Projects During 2017, as part of its renewable development strategy, Southern Power purchased wind turbine equipment from Siemens Gamesa Renewable Energy Inc. and Vestas-American Wind Technology, Inc. to be used for various development and construction projects. Any wind projects using this equipment and reaching commercial operation by the end of 2021 are expected to qualify for 80% PTCs. During 2016, Southern Power entered into a joint development agreement with Renewable Energy Systems Americas, Inc. to develop and construct wind projects. In addition, in 2016, Southern Power purchased wind turbine equipment from Siemens Wind Power, Inc. and Vestas-American Wind Technology, Inc. to be used for construction of the facilities. Any wind projects using this equipment and reaching commercial operation by the end of 2020 are expected to qualify for 100% PTCs. In response to the previously disclosed decrease of planned expenditures for plant acquisitions and placeholder growth, Southern Power continues to refine the deployment of the wind turbine equipment to potential joint development and construction projects as well as the amount of MW capacity to be constructed. During the third quarter 2018, as a result of a review of various options for probable dispositions of wind turbine equipment not already deployed to development or construction projects, Southern Power recorded a $36 million asset impairment charge on the equipment. The ultimate outcome of these matters cannot be determined at this time. Sale of Solar Facility Interests In May 2018, Southern Power sold a 33% equity interest in SPSH, a limited partnership indirectly owning substantially all of Southern Power's solar facilities, to Global Atlantic Financial Group Limited (Global Atlantic) for approximately $1.2 billion , subject to customary working capital adjustments. The proceeds were used to repay $770 million of existing indebtedness, to return capital of $250 million to Southern Company, and for other general corporate purposes, including working capital. Since Southern Power retains control of the limited partnership through its wholly-owned general partner, the sale was recorded as an equity transaction and Southern Power will continue to consolidate the results of SPSH. On the date of the transaction, the noncontrolling interest was increased by $511 million to reflect 33% of the carrying value of the partnership. This difference, partially offset by the tax impact and other related transaction charges, also resulted in a $410 million decrease to Southern Power's common stockholder's equity. Sale of Florida Plants In May 2018, Southern Power entered into an equity interest purchase agreement with NextEra Energy to sell all of its equity interests in the Florida Plants, for an aggregate purchase price of $195 million , subject to customary working capital and timing adjustments. The sale is subject to certain closing and timing conditions and approvals, including, but not limited to, approval by the FERC. The ultimate purchase price will decrease $110,000 per day for each day after December 31, 2018 through the closing of the transaction. Conversely, the ultimate purchase price will increase $110,000 per day for each day the closing occurs prior to December 31, 2018. The sale is expected to occur in the first quarter 2019. As a result of this pending transaction, Southern Power recorded an asset impairment charge of approximately $119 million ( $89 million after tax) in the second quarter 2018. The assets and liabilities of the Florida Plants are classified as assets held for sale and liabilities held for sale on Southern Company's and Southern Power's balance sheets as of September 30, 2018 . See " Assets Held for Sale " below for additional information. The ultimate outcome of this matter cannot be determined at this time. Sale of Wind Facility Interests On October 31, 2018, Southern Power entered into agreements with three financial investors for the sale of a noncontrolling interest for approximately $1.2 billion in tax equity in SP Wind, which owns a portfolio of eight operating wind facilities. The transaction is subject to Public Utility Commission of Texas approval and is expected to close by the end of 2018. Southern Power intends to use the proceeds to return capital of approximately $1.0 billion to Southern Company. The ultimate outcome of this matter cannot be determined at this time. Sale of Mankato Plant On November 5, 2018, Southern Power entered into an agreement with Northern States Power to sell all of its equity interests in Plant Mankato (including the 385 -MW expansion currently under construction) for an aggregate purchase price of $650 million , subject to customary working capital and timing adjustments. The ultimate purchase price will decrease $66,667 per day for each day after June 1, 2019, if the expansion has not achieved commercial operation, but such decrease will not exceed $15 million . This transaction is subject to the expiration or termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act and FERC and state commission approvals and is expected to close mid-2019. The ultimate outcome of this matter cannot be determined at this time. Assets Subject to Lien Under the terms of the PPA and the expansion PPA for the Mankato project, approximately $500 million of assets, primarily related to property, plant, and equipment, are subject to lien at September 30, 2018 . Southern Company Gas Sale of Pivotal Home Solutions On June 4, 2018, Southern Company Gas completed the stock sale of Pivotal Home Solutions to American Water Enterprises LLC for a total cash purchase price of $365 million , which includes the final working capital adjustment. This disposition resulted in an estimated net loss of $73 million , which includes $39 million of income tax expense, the calculation of which is expected to be finalized in the fourth quarter 2018. In contemplation of the transaction, a goodwill impairment charge of $42 million was recorded during the first quarter 2018. The after-tax loss included income tax expense on goodwill not deductible for tax purposes and for which a deferred tax liability had not been recorded previously. Southern Company Gas and American Water Enterprises LLC entered into a transition services agreement whereby Southern Company Gas provided certain administrative and operational services through November 4, 2018. Sale of Elizabethtown Gas and Elkton Gas On July 1, 2018, a Southern Company Gas subsidiary, Pivotal Utility Holdings, completed the sales of the assets of two of its natural gas distribution utilities, Elizabethtown Gas and Elkton Gas, to South Jersey Industries, Inc. for a total cash purchase price of $1.7 billion and an additional $40 million for working capital, subject to a final working capital adjustment expected in the fourth quarter 2018. This disposition resulted in an estimated pre-tax gain of approximately $230 million and an after-tax gain of approximately $18 million , the calculations of which are expected to be finalized in the fourth quarter 2018. The after-tax gain included income tax expense on goodwill not deductible for tax purposes and for which a deferred tax liability had not been recorded previously. Southern Company Gas and South Jersey Industries, Inc. entered into transition services agreements whereby Southern Company Gas will provide certain administrative and operational services through no later than January 31, 2020. Sale of Florida City Gas On July 29, 2018, Southern Company Gas and its wholly-owned direct subsidiary, NUI Corporation, completed the stock sale of Pivotal Utility Holdings, which primarily consisted of Florida City Gas, to NextEra Energy for a total cash purchase price of $530 million (less $3 million of indebtedness assumed at closing for customer deposits) and an additional $60 million for cash and other working capital, which includes the final working capital adjustment. This disposition resulted in an estimated pre-tax gain of approximately $121 million and an after-tax gain of approximately $20 million , the calculations of which are expected to be finalized in the fourth quarter 2018. The after-tax gain included income tax expense on goodwill not deductible for tax purposes and for which a deferred tax liability had not been recorded previously. Southern Company Gas and NextEra Energy entered into a transition services agreement whereby Southern Company Gas will provide certain administrative and operational services through no later than July 29, 2020. Assets Held for Sale As discussed above, Southern Company and Southern Power each have assets and liabilities held for sale on their balance sheets at September 30, 2018 . Assets and liabilities held for sale have been classified separately on each company's balance sheet at the lower of carrying value or fair value less costs to sell at the time the criteria for held-for-sale classification were met. For assets and liabilities held for sale recorded at fair value on a nonrecurring basis, the fair value of assets held for sale is based primarily on unobservable inputs (Level 3), which includes the agreed upon sales prices in executed sales agreements. Upon classification as held for sale in May 2018, Southern Power ceased recognizing depreciation on the Florida Plants' property, plant, and equipment to be sold. Since the depreciation of the assets to be sold in the Gulf Power transaction continues to be reflected in customer rates and will be reflected in the carryover basis of the assets when sold, Southern Company will continue to record depreciation on those assets through the date the transaction closes. Likewise, since the depreciation of the assets sold in the Elizabethtown Gas, Elkton Gas, and Florida City Gas transactions continued to be reflected in customer rates and was reflected in the carryover basis of the assets when sold, Southern Company Gas continued to record depreciation on those assets through the respective date that each transaction closed. The following table provides Southern Company's and Southern Power's major classes of assets and liabilities classified as held for sale at September 30, 2018 : Southern Company Southern Power (in millions) Assets Held for Sale: Current assets $ 407 $ 18 Total property, plant, and equipment 4,093 168 Other non-current assets 574 17 Total Assets Held for Sale $ 5,074 $ 203 Liabilities Held for Sale: Current liabilities $ 355 $ 4 Long-term debt 1,285 — Accumulated deferred income taxes 542 — Other non-current liabilities 1,008 — Total Liabilities Held for Sale $ 3,190 $ 4 Southern Company, Southern Power, and Southern Company Gas each concluded that the sale of their assets, both individually and combined, did not represent a strategic shift in operations 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. Gulf Power and the Florida Plants represent individually significant components of Southern Company and Southern Power, respectively; therefore, pre-tax profit for these components for the three and nine months ended September 30, 2018 and 2017 is presented below: For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Earnings before income taxes: Gulf Power $ 59 $ 103 $ 146 $ 199 Southern Power's Florida Plants $ 18 $ 11 $ 40 $ 28 |
Variable Interest Entity and Eq
Variable Interest Entity and Equity Method Investments | 9 Months Ended |
Sep. 30, 2018 | |
Regulated Operations [Abstract] | |
VARIABLE INTEREST ENTITY AND EQUITY METHOD INVESTMENTS | VARIABLE INTEREST ENTITY AND EQUITY METHOD INVESTMENTS Southern Power In May 2018, Southern Power sold a 33% limited partnership interest in SPSH to Global Atlantic. See Note (J) under "Southern Power" for additional information. A wholly-owned subsidiary of Southern Power is the general partner and holds a 1% ownership interest in SPSH and another wholly-owned subsidiary of Southern Power owns the remaining 66% ownership in SPSH. SPSH is a variable interest entity (VIE) because the arrangement is structured as a limited partnership and the 33% limited partner does not have substantive kick-out rights against the general partner. Southern Power previously consolidated SPSH and will continue to do so as the primary beneficiary of the VIE because it controls the most significant activities of the partnership, including operating and maintaining its assets. At September 30, 2018 , SPSH had total assets of $6.4 billion , total liabilities of $111 million , and noncontrolling interests related to other partners' interests of $1.2 billion . Cash distributions from SPSH are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with their membership interests and the limited partnership agreement. Transfers and sales of the assets in the VIE are subject to limited partner consent and the liabilities do not have recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt. Southern Company Gas See Note 4 to the financial statements of Southern Company Gas in Item 8 of the Form 10-K for additional information on Southern Company Gas' equity method investments. Equity Method Investments The carrying amounts of Southern Company Gas' equity method investments as of September 30, 2018 and December 31, 2017 and related income from those investments for the three and nine -month periods ended September 30, 2018 and September 30, 2017 were as follows: Investment Balance September 30, 2018 December 31, 2017 (in millions) SNG $ 1,260 $ 1,262 Atlantic Coast Pipeline 73 41 PennEast Pipeline 70 57 Other 126 117 Total $ 1,529 $ 1,477 Earnings from Equity Method Investments Three Months Ended Three Months Ended Nine Months Ended Nine Months (in millions) SNG $ 29 $ 28 $ 95 $ 86 PennEast Pipeline 2 1 4 5 Atlantic Coast Pipeline 1 1 4 4 Other 2 2 5 5 Total $ 34 $ 32 $ 108 $ 100 Southern Natural Gas Selected financial information of SNG for the three and nine months ended September 30, 2018 and September 30, 2017 is as follows: Income Statement Information Three Months Ended September 30, 2018 Three Months Ended September 30, 2017 Nine Months Ended September 30, 2018 Nine Months Ended September 30, 2017 (in millions) Revenues $ 145 $ 146 $ 451 $ 445 Operating income $ 71 $ 71 $ 230 $ 218 Net income $ 58 $ 57 $ 190 $ 172 |
Segment and Related Information
Segment and Related Information | 9 Months Ended |
Sep. 30, 2018 | |
Segment Reporting [Abstract] | |
SEGMENT AND RELATED INFORMATION | SEGMENT AND RELATED INFORMATION Southern Company The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The four traditional electric operating companies – Alabama Power, Georgia Power, Gulf Power, and Mississippi Power – are vertically integrated utilities providing electric service in four 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 its natural gas distribution utilities and is involved in several other complementary businesses including gas marketing services, wholesale gas services, and gas midstream operations. In July 2018, Southern Company Gas completed sales of three of its natural gas distribution utilities. See Note (J) under "Southern Company Gas" for additional information. Southern Company's reportable business segments are the sale of electricity by the four 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 $134 million and $326 million for the three and nine months ended September 30, 2018 , respectively, and $105 million and $295 million for the three and nine months ended September 30, 2017 , respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were $14 million and $22 million for the three and nine months ended September 30, 2018 , respectively, and $9 million and $19 million for the three and nine months ended September 30, 2017 , respectively. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $38 million and $96 million for the three and nine months ended September 30, 2018 , respectively, and $38 million and $94 million for the three and nine months ended September 30, 2017 , respectively. 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 energy technologies and services to electric utilities and large industrial, commercial, institutional, and municipal customers; as well as investments in telecommunications and leveraged lease projects. All other inter-segment revenues are not material. Financial data for business segments and products and services for the three and nine months ended September 30, 2018 and 2017 was as follows: Electric Utilities Traditional Electric Operating Companies Southern Power Eliminations Total Southern Company Gas All Other Eliminations Consolidated (in millions) Three Months Ended September 30, 2018: Operating revenues $ 5,014 $ 635 $ (140 ) $ 5,509 $ 492 $ 202 $ (44 ) $ 6,159 Segment net income (loss) (a)(b)(c)(d) 1,148 92 — 1,240 46 (119 ) (3 ) 1,164 Nine Months Ended September 30, 2018: Operating revenues $ 13,117 $ 1,699 $ (360 ) $ 14,456 $ 2,861 $ 984 $ (143 ) $ 18,158 Segment net income (loss) (a)(b)(c)(d) 1,711 235 — 1,946 294 (292 ) — 1,948 At September 30, 2018: Goodwill $ — $ 2 $ — $ 2 $ 5,015 $ 298 $ — $ 5,315 Total assets 75,069 15,355 (322 ) 90,102 20,398 3,086 (1,869 ) 111,717 Three Months Ended September 30, 2017: Operating revenues $ 5,017 $ 618 $ (112 ) $ 5,523 $ 565 $ 153 $ (40 ) $ 6,201 Segment net income (loss) (a)(b) 1,008 124 — 1,132 15 (80 ) 2 1,069 Nine Months Ended September 30, 2017: Operating revenues $ 12,960 $ 1,597 $ (318 ) $ 14,239 $ 2,841 $ 442 $ (119 ) $ 17,403 Segment net income (loss) (a)(b)(e) — 276 — 276 303 (232 ) — 347 At December 31, 2017: Goodwill $ — $ 2 $ — $ 2 $ 5,967 $ 299 $ — $ 6,268 Total assets 72,204 15,206 (325 ) 87,085 22,987 2,552 (1,619 ) 111,005 (a) Attributable to Southern Company. (b) Segment net income (loss) for the traditional electric operating companies includes pre-tax charges for estimated losses on plants under construction of $1 million ( $1 million after tax) and $34 million ( $21 million after tax) for the three months ended September 30, 2018 and 2017 , respectively, and $1.1 billion ( $0.8 billion after tax) and $3.2 billion ( $2.2 billion after tax) for the nine months ended September 30, 2018 and 2017 , respectively. See Note 3 to the financial statements of Southern Company under "Kemper County Energy Facility" in Item 8 of the Form 10-K and Note (B) under " Nuclear Construction " and " Kemper County Energy Facility " for additional information. (c) Segment net income (loss) for Southern Power includes pre-tax impairment charges of $36 million ( $27 million after tax) and $155 million ( $116 million after tax) for the three and nine months ended September 30, 2018, respectively. See Note (J) under "Southern Power – Development Projects " and " – Sale of Florida Plants " for additional information. (d) Segment net income (loss) for Southern Company Gas includes a net gain on dispositions of $353 million ( $40 million gain after tax) and $317 million ( $35 million loss after tax) for the three and nine months ended September 30, 2018, respectively, related to the Southern Company Gas Dispositions and a goodwill impairment charge of $42 million for the nine months ended September 30, 2018 related to the sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas " for additional information. (e) Segment net income (loss) for the traditional electric operating companies includes a pre-tax charge for the write-down of Gulf Power's ownership of Plant Scherer Unit 3 of $33 million ( $20 million after tax) for the nine months ended September 30, 2017. See Note 3 to the financial statements of Southern Company under "Regulatory Matters – Gulf Power – Retail Base Rate Cases" in Item 8 of the Form 10-K for additional information. Products and Services Electric Utilities' Revenues Period Retail Wholesale Other Total (in millions) Three Months Ended September 30, 2018 $ 4,605 $ 693 $ 211 $ 5,509 Three Months Ended September 30, 2017 4,615 718 190 5,523 Nine Months Ended September 30, 2018 $ 11,913 $ 1,923 $ 620 $ 14,456 Nine Months Ended September 30, 2017 11,786 1,867 586 14,239 Southern Company Gas' Revenues Period Gas Gas Other Total (in millions) Three Months Ended September 30, 2018 $ 438 $ 44 $ 10 $ 492 Three Months Ended September 30, 2017 430 143 (8 ) 565 Nine Months Ended September 30, 2018 $ 2,276 $ 403 $ 182 $ 2,861 Nine Months Ended September 30, 2017 2,119 597 125 2,841 Southern Company Gas Southern Company Gas manages its business through four reportable segments – gas distribution operations, gas marketing services, wholesale gas services, and gas midstream operations. The non-reportable segments are combined and presented as all other. 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 seven states. In July 2018, Southern Company Gas sold three of its natural gas distribution utilities, Elizabethtown Gas, Elkton Gas, and Florida City Gas. See Note (J) under "Southern Company Gas" for additional information. Gas marketing services includes natural gas marketing to end-use customers primarily in Georgia and Illinois. On June 4, 2018, Southern Company Gas sold Pivotal Home Solutions. See Note (J) under "Southern Company Gas" for additional information. Wholesale gas services provides 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 engages in natural gas storage and gas pipeline arbitrage and related activities. Gas midstream operations primarily consists of Southern Company Gas' pipeline investments, with storage and fuel operations also aggregated into this segment. The all other column includes segments below the quantitative threshold for separate disclosure, including the subsidiaries that fall below the quantitative threshold for separate disclosure. Business segment financial data for the three and nine months ended September 30, 2018 and 2017 was as follows: Gas Distribution Operations (a)(c) Gas Marketing Services (b)(c) Wholesale Gas Services (d) Gas Midstream Operations Total All Other Eliminations Consolidated (in millions) Three Months Ended September 30, 2018: Operating revenues $ 441 $ 44 $ (8 ) $ 20 $ 497 $ 1 $ (6 ) $ 492 Segment net income (loss) 74 (8 ) (18 ) 16 64 (18 ) — 46 Nine Months Ended September 30, 2018: Operating revenues 2,297 403 142 60 2,902 3 (44 ) 2,861 Segment net income (loss) 290 (71 ) 65 54 338 (44 ) — 294 Total assets at September 30, 2018: 16,850 1,522 855 2,297 21,524 10,146 (11,272 ) 20,398 Three Months Ended September 30, 2017: Operating revenues $ 472 $ 143 $ (24 ) $ 16 $ 607 $ 2 $ (44 ) $ 565 Segment net income (loss) 52 1 (23 ) 14 44 (29 ) — 15 Nine Months Ended September 30, 2017: Operating revenues 2,255 597 95 53 3,000 7 (166 ) 2,841 Segment net income (loss) 223 36 28 38 325 (22 ) — 303 Total assets at December 31, 2017: 19,358 2,147 1,096 2,241 24,842 12,184 (14,039 ) 22,987 (a) Operating revenues for the three gas distribution operations dispositions were $8 million and $50 million for the three months ended September 30, 2018 and 2017 , respectively, and $245 million and $274 million for the nine months ended September 30, 2018 and 2017 , respectively. See Note (J) under " Southern Company Gas " for additional information. (b) Operating revenues for the gas marketing services disposition were $32 million for the three months ended September 30, 2017 and $55 million and $95 million for the nine months ended September 30, 2018 and 2017 , respectively. See Note (J) under " Southern Company Gas " for additional information. (c) Segment net income for gas distribution operations includes a gain on dispositions of $351 million ( $38 million after tax) for the three and nine months ended September 30, 2018 . Segment net income for gas marketing services includes a gain on disposition of $2 million ( $2 million after tax) for the three months ended September 30, 2018 and a loss on disposition of $34 million ( $73 million loss after tax) and a goodwill impairment charge of $42 million for the nine months ended September 30, 2018 recorded in contemplation of the sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas " for additional information. (d) The revenues for wholesale gas services are 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) Three Months Ended September 30, 2018 $ 1,573 $ 82 $ 1,655 $ 1,663 $ (8 ) Three Months Ended September 30, 2017 1,411 103 1,514 1,538 (24 ) Nine Months Ended September 30, 2018 $ 4,847 $ 352 $ 5,199 $ 5,057 $ 142 Nine Months Ended September 30, 2017 4,781 362 5,143 5,048 95 |
Introduction (Policies)
Introduction (Policies) | 9 Months Ended |
Sep. 30, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Accounting | The condensed quarterly financial statements of each registrant included herein have been prepared by such registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets as of December 31, 2017 have been derived from the audited financial statements of each registrant. In the opinion of each registrant's management, the information regarding such registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended September 30, 2018 and 2017 . Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each registrant believes that the disclosures regarding such registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year. |
Reclassification | Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the results of operations, financial position, or cash flows of any registrant. |
Recently Adopted Accounting Standards | Recently Adopted Accounting Standards See Note 1 to the financial statements of the registrants under "Recently Issued Accounting Standards" in Item 8 of the Form 10-K for additional information. Revenue In 2014, the FASB issued ASC 606, Revenue from Contracts with Customers (ASC 606), replacing the existing accounting standard and industry-specific guidance for revenue recognition with a five-step model for recognizing and measuring revenue from contracts with customers. The underlying principle of the standard is to recognize revenue to depict the transfer of goods or services to customers at the amount expected to be collected. ASC 606 became effective on January 1, 2018 and the registrants adopted it using the modified retrospective method applied to open contracts and only to the version of the contracts in effect as of January 1, 2018. In accordance with the modified retrospective method, the registrants' previously issued financial statements have not been restated to comply with ASC 606 and the registrants did not have a cumulative-effect adjustment to retained earnings. The adoption of ASC 606 had no significant impact on the timing of revenue recognition compared to previously reported results; however, it requires enhanced disclosures regarding the nature, amount, timing, and uncertainty of revenue and the related cash flows arising from contracts with customers, which are included in Note (C). ASC 606 provided additional clarity on financial statement presentation that resulted in reclassifications into other revenues and other operations and maintenance from other income/(expense), net at Alabama Power and Georgia Power related to certain unregulated sales of products and services. In addition, contract assets related to certain fixed retail revenues at Georgia Power and Southern Company's unregulated distributed generation business have been reclassified from unbilled revenue in accordance with the guidance in ASC 606. These reclassifications did not affect the timing or amount of revenues recognized or cash flows. ASC 606 also provided additional guidance on revenue recognized over time, resulting in a change in the timing of revenue recognized from guaranteed and fixed billing arrangements at Southern Company Gas. The changes in natural gas revenues recognized in the third quarter and year-to-date 2018 relate primarily to the seasonal nature of natural gas usage. The net impact of accounting for revenue under ASC 606 decreased Southern Company's and Southern Company Gas' consolidated net income by $4 million for the three months ended September 30, 2018 and increased Southern Company's and Southern Company Gas' consolidated net income by $1 million for the nine months ended September 30, 2018 . The specific impacts of applying ASC 606 to revenues from contracts with customers on the financial statements of Southern Company, Alabama Power, Georgia Power, and Southern Company Gas compared to previously recognized guidance is shown below. For the Three Months Ended For the Nine Months Ended Condensed Statements of Income As Reported Balances Without Adoption of Effect of Change As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) (in millions) Southern Company Natural gas revenues $ 492 $ 497 $ (5 ) $ 2,806 $ 2,805 $ 1 Other revenues 199 198 1 1,007 1,003 4 Other operations and maintenance 1,404 1,387 17 4,217 4,178 39 Operating income 2,174 2,195 (21 ) 3,613 3,647 (34 ) Other income (expense), net 57 41 16 195 160 35 Earnings (loss) before income taxes 1,845 1,850 (5 ) 2,629 2,628 1 Income taxes (benefit) 623 624 (1 ) 598 598 — Consolidated net income (loss) 1,222 1,226 (4 ) 2,031 2,030 1 Consolidated net income (loss) attributable to Southern Company 1,164 1,168 (4 ) 1,948 1,947 1 Alabama Power Other revenues $ 68 $ 59 $ 9 $ 199 $ 173 $ 26 Other operations and maintenance 401 390 11 1,191 1,159 32 Operating income 561 563 (2 ) 1,313 1,319 (6 ) Other income (expense), net 9 7 2 24 18 6 Georgia Power Other revenues $ 121 $ 97 $ 24 $ 349 $ 287 $ 62 Other operations and maintenance 460 437 23 1,325 1,268 57 Operating income (loss) 991 990 1 1,032 1,027 5 Other income (expense), net 30 31 (1 ) 104 109 (5 ) Southern Company Gas Natural gas revenues $ 487 $ 492 $ (5 ) $ 2,829 $ 2,828 $ 1 Operating income 374 379 (5 ) 810 809 1 Earnings before income taxes 362 367 (5 ) 769 768 1 Income taxes 316 317 (1 ) 475 475 — Net income (loss) 46 50 (4 ) 294 293 1 For the Nine Months Ended Condensed Statements of Cash Flows As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Consolidated net income $ 2,031 $ 2,030 $ 1 Changes in certain current assets and liabilities: Receivables 37 27 10 Other current assets (90 ) (80 ) (10 ) Other current liabilities (67 ) (68 ) 1 Georgia Power Changes in certain current assets and liabilities: Receivables $ (205 ) $ (242 ) $ 37 Other current assets (36 ) 1 (37 ) Southern Company Gas Net income $ 294 $ 293 $ 1 Changes in certain current assets and liabilities: Other current liabilities 35 34 1 At September 30, 2018 Condensed Balance Sheets As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Unbilled revenues $ 738 $ 776 $ (38 ) Other accounts and notes receivable 690 691 (1 ) Other current assets 232 193 39 Other current liabilities 763 764 (1 ) Retained earnings 9,048 9,047 1 Georgia Power Unbilled revenues $ 245 $ 310 $ (65 ) Other accounts and notes receivable 96 97 (1 ) Other current assets 91 25 66 Southern Company Gas Other current liabilities 122 123 (1 ) Accumulated deficit (273 ) (274 ) 1 Other In 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (ASU 2016-18). ASU 2016-18 eliminates the need to reflect transfers between cash and restricted cash in operating, investing, and financing activities in the statements of cash flows. In addition, the net change in cash and cash equivalents during the period includes amounts generally described as restricted cash or restricted cash equivalents. The registrants adopted ASU 2016-18 effective January 1, 2018 with no material impact on their financial statements. Southern Company, Southern Power, and Southern Company Gas retrospectively applied ASU 2016-18 effective January 1, 2018 and have restated prior periods in the statements of cash flows by immaterial amounts. The change in restricted cash in the statements of cash flows was previously disclosed in operating activities for Southern Company and Southern Company Gas and in investing activities for Southern Company and Southern Power. See " Restricted Cash " herein for additional information. In March 2017, the FASB issued ASU No. 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (ASU 2017-07). ASU 2017-07 requires that an employer report the service cost component in the same line item or items as other compensation costs and requires the other components of net periodic pension and postretirement benefit costs to be separately presented in the statements of income outside of income from operations. Additionally, only the service cost component is eligible for capitalization, when applicable. The registrants adopted ASU 2017-07 effective January 1, 2018 with no material impact on their financial statements. ASU 2017-07 has been applied retrospectively for the presentation of the service cost component and the other components of net periodic benefit costs in the statements of income for Southern Company, the traditional electric operating companies, and Southern Company Gas. Since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017, no retrospective presentation of Southern Power's net periodic benefits costs is required. The requirement to limit capitalization to the service cost component of net periodic benefit costs has been applied on a prospective basis from the date of adoption for all registrants. The presentation changes resulted in a decrease in operating income and an increase in other income for the three and nine months ended September 30, 2018 and 2017 for Southern Company, the traditional electric operating companies, and Southern Company Gas. In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities (ASU 2017-12). ASU 2017-12 makes more financial and non-financial hedging strategies eligible for hedge accounting, amends the related presentation and disclosure requirements, and simplifies hedge effectiveness assessment requirements. ASU 2017-12 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The registrants adopted ASU 2017-12 effective January 1, 2018 with no material impact on their financial statements. See Note (I) for disclosures required by ASU 2017-12. On February 14, 2018, the FASB issued ASU No. 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income (ASU 2018-02) to address the application of ASC 740, Income Taxes (ASC 740) to certain provisions of the Tax Reform Legislation. ASU 2018-02 specifically addresses the ASC 740 requirement that the effect of a change in tax laws or rates on deferred tax assets and liabilities be included in income from continuing operations, even when the tax effects were initially recognized directly in OCI at the previous rate, which strands the income tax rate differential in accumulated OCI. The amendments in ASU 2018-02 allow a reclassification from accumulated OCI to retained earnings for stranded tax effects resulting from the Tax Reform Legislation. The registrants adopted ASU 2018-02 effective January 1, 2018 with no material impact on their financial statements. |
Goodwill and Other Intangible Assets | Goodwill is not amortized but is subject to an annual impairment test during the fourth quarter of each year or more frequently if impairment indicators arise. |
Restricted Cash | Restricted Cash The registrants adopted ASU 2016-18 as of January 1, 2018. See " Recently Adopted Accounting Standards – Other " herein for additional information. At December 31, 2017 , Southern Power had restricted cash primarily related to certain acquisitions and construction projects. At both September 30, 2018 and December 31, 2017 , Southern Company Gas had restricted cash held as collateral for worker's compensation, life insurance, and long-term disability insurance. |
Natural Gas For Sale | Natural Gas for Sale Southern Company Gas' natural gas distribution utilities, with the exception of Nicor Gas, carry natural gas inventory on a WACOG basis. 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. Southern Company Gas had no inventory decrement at September 30, 2018 . 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. Natural gas inventories for Southern Company Gas' non-utility businesses are carried at the lower of weighted average cost or current market price, with cost determined on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. |
Hypothetical Liquidation at Book Value | Hypothetical Liquidation at Book Value Southern Power has consolidated renewable generation projects that are partially funded by a third-party tax equity investor. The related contractual provisions represent profit-sharing arrangements because the allocations of cash distributions and tax benefits are not based on fixed ownership percentages. Therefore, the noncontrolling interest is accounted for under a balance sheet approach utilizing the hypothetical liquidation at book value (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 hypothetical liquidation at the end of the period compared to the beginning of the period. |
Valuation Methodologies | 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 (I) 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 1 to the financial statements of Southern Company, Alabama Power, and Georgia Power under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information. Southern Power has contingent payment obligations related to certain acquisitions whereby Southern Power is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation date of the respective facility and continue through 2026. The obligation is categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility 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. "Other investments" include investments that are not traded in the open market. The fair value of these investments has been determined based on market factors including comparable multiples and the expectations regarding cash flows and business plan executions. |
Earnings per Share | Earnings per Share For Southern Company, the only difference in computing basic and diluted earnings per share is attributable to awards outstanding under stock-based compensation plans. See Note 8 to the financial statements of Southern Company in Item 8 of the Form 10-K for information on stock-based compensation plans. The effect of stock-based compensation plans was determined using the treasury stock method. |
Derivatives | Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company Gas' wholesale gas operations use various contracts in its commercial activities that generally meet the definition of derivatives. 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 (D) for additional information. In the statements of cash flows, the cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. The cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with classification of the hedged interest or principal, respectively. The registrants adopted ASU 2017-12 as of January 1, 2018. See Note (A) under " Recently Adopted Accounting Standards – Other " for additional information. Energy-Related Derivatives Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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 is expected to continue to mitigate price volatility. The Florida PSC approved a moratorium on Gulf Power's fuel-hedging program until January 1, 2021. The moratorium does not have an impact on the recovery of existing hedges entered into under the previously-approved hedging program. 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 of operating margins 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 which are 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 the respective fuel cost recovery clauses. • 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 OCI 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. Foreign Currency Derivatives Southern Company and certain subsidiaries may also 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. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. Interest Rate Derivatives Southern Company and certain subsidiaries may also enter into interest rate derivatives to hedge exposure to changes in interest rates. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. 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. |
Introduction (Tables)
Introduction (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Schedule of New Accounting Pronouncements and Changes in Accounting Principles | The specific impacts of applying ASC 606 to revenues from contracts with customers on the financial statements of Southern Company, Alabama Power, Georgia Power, and Southern Company Gas compared to previously recognized guidance is shown below. For the Three Months Ended For the Nine Months Ended Condensed Statements of Income As Reported Balances Without Adoption of Effect of Change As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) (in millions) Southern Company Natural gas revenues $ 492 $ 497 $ (5 ) $ 2,806 $ 2,805 $ 1 Other revenues 199 198 1 1,007 1,003 4 Other operations and maintenance 1,404 1,387 17 4,217 4,178 39 Operating income 2,174 2,195 (21 ) 3,613 3,647 (34 ) Other income (expense), net 57 41 16 195 160 35 Earnings (loss) before income taxes 1,845 1,850 (5 ) 2,629 2,628 1 Income taxes (benefit) 623 624 (1 ) 598 598 — Consolidated net income (loss) 1,222 1,226 (4 ) 2,031 2,030 1 Consolidated net income (loss) attributable to Southern Company 1,164 1,168 (4 ) 1,948 1,947 1 Alabama Power Other revenues $ 68 $ 59 $ 9 $ 199 $ 173 $ 26 Other operations and maintenance 401 390 11 1,191 1,159 32 Operating income 561 563 (2 ) 1,313 1,319 (6 ) Other income (expense), net 9 7 2 24 18 6 Georgia Power Other revenues $ 121 $ 97 $ 24 $ 349 $ 287 $ 62 Other operations and maintenance 460 437 23 1,325 1,268 57 Operating income (loss) 991 990 1 1,032 1,027 5 Other income (expense), net 30 31 (1 ) 104 109 (5 ) Southern Company Gas Natural gas revenues $ 487 $ 492 $ (5 ) $ 2,829 $ 2,828 $ 1 Operating income 374 379 (5 ) 810 809 1 Earnings before income taxes 362 367 (5 ) 769 768 1 Income taxes 316 317 (1 ) 475 475 — Net income (loss) 46 50 (4 ) 294 293 1 For the Nine Months Ended Condensed Statements of Cash Flows As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Consolidated net income $ 2,031 $ 2,030 $ 1 Changes in certain current assets and liabilities: Receivables 37 27 10 Other current assets (90 ) (80 ) (10 ) Other current liabilities (67 ) (68 ) 1 Georgia Power Changes in certain current assets and liabilities: Receivables $ (205 ) $ (242 ) $ 37 Other current assets (36 ) 1 (37 ) Southern Company Gas Net income $ 294 $ 293 $ 1 Changes in certain current assets and liabilities: Other current liabilities 35 34 1 At September 30, 2018 Condensed Balance Sheets As Reported Balances Without Adoption of ASC 606 Effect of Change (in millions) Southern Company Unbilled revenues $ 738 $ 776 $ (38 ) Other accounts and notes receivable 690 691 (1 ) Other current assets 232 193 39 Other current liabilities 763 764 (1 ) Retained earnings 9,048 9,047 1 Georgia Power Unbilled revenues $ 245 $ 310 $ (65 ) Other accounts and notes receivable 96 97 (1 ) Other current assets 91 25 66 Southern Company Gas Other current liabilities 122 123 (1 ) Accumulated deficit (273 ) (274 ) 1 |
Schedule of Change in Asset Retirement Obligation | As of September 30, 2018 , details of the AROs, including those related to the CCR Rule, included in the condensed balance sheets of Southern Company, Alabama Power, Georgia Power, Gulf Power, and Mississippi Power were as follows: Southern Company Alabama Power Georgia Power Gulf Mississippi Power (in millions) Balance at December 31, 2017 $ 4,824 $ 1,709 $ 2,638 $ 142 $ 174 Liabilities incurred 2 — — — — Liabilities settled (160 ) (31 ) (82 ) (23 ) (22 ) Accretion 153 72 70 3 4 Cash flow revisions 1,510 1,451 (32 ) 42 21 Reclassification to held for sale (164 ) — — — — Balance at September 30, 2018 $ 6,165 $ 3,201 $ 2,594 $ 164 $ 177 |
Estimated Cost Of Decommissioning | In June 2018, Alabama Power completed an updated decommissioning cost site study for Plant Farley. The estimated costs of decommissioning based on the 2018 site study are as follows: Decommissioning periods: Beginning year 2037 Completion year 2076 (in millions) Site study costs: Radiated structures $ 1,621 Non-radiated structures 99 Total site study costs $ 1,720 |
Schedule of Goodwill | The following table presents year-to-date changes in goodwill balances for Southern Company and Southern Company Gas: Goodwill Southern Company Southern Company Gas Gas Distribution Operations Gas Marketing Services Total (in millions) Balance at December 31, 2017 $ 6,268 $ 4,702 $ 1,265 $ 5,967 Impairment (a) (42 ) — (42 ) (42 ) Dispositions (b) (910 ) (668 ) (242 ) (910 ) Balance at September 30, 2018 $ 5,315 (c) $ 4,034 $ 981 $ 5,015 (a) On April 11, 2018, Southern Company Gas entered into a stock purchase agreement for the sale of Pivotal Home Solutions. In contemplation of the transaction, a goodwill impairment charge of $42 million was recorded in the first quarter 2018. See Note (J) under " Southern Company Gas " for additional information. (b) Gas distribution operations reflects goodwill allocated to Elizabethtown Gas, Elkton Gas, and Florida City Gas, which were sold during the third quarter 2018. Gas marketing services reflects goodwill associated with Pivotal Home Solutions, which was sold on June 4, 2018. See Note (J) under " Southern Company Gas " for additional information. (c) Total does not add due to rounding. |
Schedule of Other Intangible Assets, Finite-Lived | Other intangible assets were as follows: At September 30, 2018 At December 31, 2017 Gross Carrying Amount Accumulated Amortization Other Intangible Assets, Net Gross Carrying Amount Accumulated Amortization Other (in millions) (in millions) Southern Company Other intangible assets subject to amortization: Customer relationships (*) $ 223 $ (87 ) $ 136 $ 288 $ (83 ) $ 205 Trade names (*) 70 (18 ) 52 159 (17 ) 142 Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 PPA fair value adjustments 456 (66 ) 390 456 (47 ) 409 Other 11 (5 ) 6 17 (5 ) 12 Total other intangible assets subject to amortization $ 824 $ (225 ) $ 599 $ 984 $ (186 ) $ 798 Other intangible assets not subject to amortization: Federal Communications Commission licenses 75 — 75 75 — 75 Total other intangible assets $ 899 $ (225 ) $ 674 $ 1,059 $ (186 ) $ 873 Southern Power Other intangible assets subject to amortization: PPA fair value adjustments $ 456 $ (66 ) $ 390 $ 456 $ (47 ) $ 409 Southern Company Gas Other intangible assets subject to amortization: Gas marketing services (*) Customer relationships $ 156 $ (78 ) $ 78 $ 221 $ (77 ) $ 144 Trade names 26 (6 ) 20 115 (9 ) 106 Wholesale gas services Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 Total other intangible assets subject to amortization $ 246 $ (133 ) $ 113 $ 400 $ (120 ) $ 280 (*) Balances as of September 30, 2018 reflect Southern Company Gas' sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas – Sale of Pivotal Home Solutions " for additional information. |
Schedule of Other Intangible Assets, Indefinite-Lived | Other intangible assets were as follows: At September 30, 2018 At December 31, 2017 Gross Carrying Amount Accumulated Amortization Other Intangible Assets, Net Gross Carrying Amount Accumulated Amortization Other (in millions) (in millions) Southern Company Other intangible assets subject to amortization: Customer relationships (*) $ 223 $ (87 ) $ 136 $ 288 $ (83 ) $ 205 Trade names (*) 70 (18 ) 52 159 (17 ) 142 Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 PPA fair value adjustments 456 (66 ) 390 456 (47 ) 409 Other 11 (5 ) 6 17 (5 ) 12 Total other intangible assets subject to amortization $ 824 $ (225 ) $ 599 $ 984 $ (186 ) $ 798 Other intangible assets not subject to amortization: Federal Communications Commission licenses 75 — 75 75 — 75 Total other intangible assets $ 899 $ (225 ) $ 674 $ 1,059 $ (186 ) $ 873 Southern Power Other intangible assets subject to amortization: PPA fair value adjustments $ 456 $ (66 ) $ 390 $ 456 $ (47 ) $ 409 Southern Company Gas Other intangible assets subject to amortization: Gas marketing services (*) Customer relationships $ 156 $ (78 ) $ 78 $ 221 $ (77 ) $ 144 Trade names 26 (6 ) 20 115 (9 ) 106 Wholesale gas services Storage and transportation contracts 64 (49 ) 15 64 (34 ) 30 Total other intangible assets subject to amortization $ 246 $ (133 ) $ 113 $ 400 $ (120 ) $ 280 (*) Balances as of September 30, 2018 reflect Southern Company Gas' sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas – Sale of Pivotal Home Solutions " for additional information. |
Finite-lived Intangible Assets Amortization Expense | Amortization associated with other intangible assets was as follows: Three Months Ended Nine Months Ended September 30, 2018 (in millions) Southern Company $ 21 $ 70 Southern Power $ 6 $ 19 Southern Company Gas $ 12 $ 42 |
Schedule of Cash and Cash Equivalents | The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at September 30, 2018 and/or December 31, 2017 : Southern Company Southern Company Gas (in millions) At September 30, 2018 Cash and cash equivalents $ 1,847 $ 56 Cash and cash equivalents classified as assets held for sale 37 — Restricted cash: Other accounts and notes receivable 6 6 Total cash, cash equivalents, and restricted cash $ 1,891 (*) $ 62 (*) Total does not add due to rounding. Southern Company Southern Power Southern Company Gas (in millions) At December 31, 2017 Cash and cash equivalents $ 2,130 $ 129 $ 73 Restricted cash: Other accounts and notes receivable 5 — 5 Deferred charges and other assets 12 11 — Total cash, cash equivalents, and restricted cash $ 2,147 $ 140 $ 78 |
Restrictions on Cash and Cash Equivalents | The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at September 30, 2018 and/or December 31, 2017 : Southern Company Southern Company Gas (in millions) At September 30, 2018 Cash and cash equivalents $ 1,847 $ 56 Cash and cash equivalents classified as assets held for sale 37 — Restricted cash: Other accounts and notes receivable 6 6 Total cash, cash equivalents, and restricted cash $ 1,891 (*) $ 62 (*) Total does not add due to rounding. Southern Company Southern Power Southern Company Gas (in millions) At December 31, 2017 Cash and cash equivalents $ 2,130 $ 129 $ 73 Restricted cash: Other accounts and notes receivable 5 — 5 Deferred charges and other assets 12 11 — Total cash, cash equivalents, and restricted cash $ 2,147 $ 140 $ 78 |
Contingencies and Regulatory _2
Contingencies and Regulatory Matters (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
Cost Recovery Clauses | The balance of each regulatory clause recovery on the balance sheet follows: Regulatory Clause Balance Sheet Line Item September 30, December 31, (in millions) Rate CNP Compliance Deferred under recovered regulatory clause revenues $ — $ 17 Under recovered regulatory clause revenues 7 — Rate CNP PPA Deferred under recovered regulatory clause revenues 30 12 Retail Energy Cost Recovery Deferred under recovered regulatory clause revenues 58 25 Under recovered regulatory clause revenues 41 — Natural Disaster Reserve Other regulatory liabilities, deferred 24 38 Regulatory clause recovery balances included in the balance sheets are as follows: Regulatory Clause Balance Sheet Line Item September 30, December 31, (in millions) Fuel Cost Recovery Under recovered regulatory clause revenues $ — $ 22 Fuel Cost Recovery Other regulatory liabilities, current 23 — Purchased Power Capacity Recovery Other regulatory liabilities, current 4 — Purchased Power Capacity Recovery Under recovered regulatory clause revenues — 2 Environmental Cost Recovery (*) Other regulatory liabilities, current 13 — Environmental Cost Recovery (*) Under recovered regulatory clause revenues — 2 Energy Conservation Cost Recovery Other regulatory liabilities, current 2 — (*) At September 30, 2018 and December 31, 2017 , the over and under recovered balances, respectively, included in the balance sheets represents the current portion of the regulatory assets associated with projected environmental expenditures of approximately $8 million and $13 million , respectively, net of the over recovered environmental cost recovery balance of approximately $21 million and $11 million , respectively. |
Cost and Schedule | Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows: (in billions) Base project capital cost forecast (a)(b) $ 8.0 Construction contingency estimate 0.4 Total project capital cost forecast (a)(b) 8.4 Net investment as of September 30, 2018 (b) (4.3 ) Remaining estimate to complete (a) $ 4.1 (a) Excludes financing costs expected to be capitalized through AFUDC of approximately $350 million . (b) Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds. |
Revenue from Contracts with C_2
Revenue from Contracts with Customers (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Revenue from Contract with Customer [Abstract] | |
Disaggregation of Revenue | The following tables disaggregate revenue sources for the three and nine months ended September 30, 2018 : For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Company Operating revenues Retail electric revenues (a) Residential $ 2,148 $ 5,266 Commercial 1,527 4,084 Industrial 901 2,471 Other 29 92 Natural gas distribution revenues 433 2,299 Alternative revenue programs (b) 5 (23 ) Total retail electric and gas distribution revenues $ 5,043 $ 14,189 Wholesale energy revenues (c)(d) 516 1,444 Wholesale capacity revenues (d) 177 479 Other natural gas revenues (e) 54 530 Other revenues (f) 369 1,516 Total operating revenues $ 6,159 $ 18,158 (a) Retail electric revenues include $17 million and $54 million of leases for the three and nine months ended September 30, 2018 , respectively, and a (net reduction) or net increase of $(98) million and $4 million for the three and nine months ended September 30, 2018 , respectively, from certain cost recovery mechanisms that are not accounted for as revenue under ASC 606. See Note 3 to the financial statements of Southern Company under "Regulatory Matters" in Item 8 of the Form 10-K for additional information on cost recovery mechanisms. (b) See Note 1 to the financial statements of Southern Company under "Revenues" in Item 8 of the Form 10-K for additional information on alternative revenue programs at the natural gas distribution utilities. Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period. (c) Wholesale energy revenues include $63 million and $217 million for the three and nine months ended September 30, 2018 , respectively, of revenues accounted for as derivatives, primarily related to physical energy sales in the wholesale electricity market. See Note (I) for additional information on energy-related derivative contracts. (d) Wholesale energy and wholesale capacity revenues include $130 million and $31 million , respectively, for the three months ended September 30, 2018 and $318 million and $92 million , respectively, for the nine months ended September 30, 2018 of PPA contracts accounted for as leases. (e) Other natural gas revenues related to Southern Company Gas' energy and risk management activities are presented net of the related costs of those activities and include gross third-party revenues of $1.6 billion and $4.8 billion for the three and nine months ended September 30, 2018 , respectively, of which $0.9 billion and $2.7 billion , respectively, relates to contracts that are accounted for as derivatives. See Note (L) under " Southern Company Gas " for additional information on the components of wholesale gas services operating revenues. (f) Other revenues include $92 million and $274 million for the three and nine months ended September 30, 2018 , respectively, of revenues not accounted for under ASC 606. Alabama Power Georgia Power Gulf Power Mississippi Power (in millions) For the Three Months Ended September 30, 2018 Operating revenues Retail revenues (a)(b) Residential $ 721 $ 1,142 $ 200 $ 85 Commercial 464 877 103 82 Industrial 392 385 37 86 Other 7 21 1 1 Total retail electric revenues $ 1,584 $ 2,425 $ 341 $ 254 Wholesale energy revenues (c) 62 33 48 92 Wholesale capacity revenues 26 14 7 1 Other revenues (b)(d) 68 121 18 11 Total operating revenues $ 1,740 $ 2,593 $ 414 $ 358 For the Nine Months Ended September 30, 2018 Operating revenues Retail revenues (a)(b) Residential $ 1,848 $ 2,671 $ 537 $ 209 Commercial 1,238 2,343 291 212 Industrial 1,103 1,036 100 233 Other 19 62 4 6 Total retail electric revenues $ 4,208 $ 6,112 $ 932 $ 660 Wholesale energy revenues (c) 234 99 104 259 Wholesale capacity revenues 75 41 20 6 Other revenues (b)(d) 199 349 50 31 Total operating revenues $ 4,716 $ 6,601 $ 1,106 $ 956 (a) Retail revenues at Alabama Power, Georgia Power, Gulf Power, and Mississippi Power include a net increase or (net reduction) of $(12) million , $(47) million , $(36) million , and $(3) million , respectively, for the three months ended September 30, 2018 and $113 million , $(35) million , $(63) million , and $(11) million , respectively, for the nine months ended September 30, 2018 related to certain cost recovery mechanisms that are not accounted for as revenue under ASC 606. See Note 3 to the financial statements of Alabama Power, Georgia Power, Gulf Power, and Mississippi Power under "Retail Regulatory Matters" in Item 8 of the Form 10-K for additional information on cost recovery mechanisms. (b) Retail revenues and other revenues at Georgia Power include $17 million and $34 million , respectively, for the three months ended September 30, 2018 and $54 million and $100 million , respectively, for the nine months ended September 30, 2018 of revenues accounted for as leases. (c) Wholesale energy revenues at Alabama Power and Georgia Power include $6 million and $8 million , respectively, for the three months ended September 30, 2018 and $14 million and $21 million , respectively, for the nine months ended September 30, 2018 accounted for as derivatives primarily related to physical energy sales in the wholesale electricity market. See Note (I) for additional information on energy-related derivative contracts. (d) Other revenues at Alabama Power, Georgia Power, and Gulf Power include $27 million , $28 million , and $2 million , respectively, for the three months ended September 30, 2018 and $79 million , $80 million , and $5 million , respectively, for the nine months ended September 30, 2018 of revenues not accounted for under ASC 606. For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Power PPA capacity revenues (a) $ 168 $ 450 PPA energy revenues (a) 336 892 Non-PPA revenues (b) 126 347 Other revenues 5 10 Total operating revenues $ 635 $ 1,699 (a) PPA capacity revenues and PPA energy revenues include $47 million and $139 million , respectively, for the three months ended September 30, 2018 and $141 million and $342 million , respectively, for the nine months ended September 30, 2018 related to PPAs accounted for as leases. See Note 1 to the financial statements of Southern Power under "Revenues" in Item 8 of the Form 10-K for additional information on capacity revenues accounted for as leases. (b) Non-PPA revenues include $47 million and $176 million for the three and nine months ended September 30, 2018 , respectively, of revenues from short-term sales related to physical energy sales from uncovered capacity in the wholesale electricity market. See Note 1 to the financial statements of Southern Power under "Revenues" in Item 8 of the Form 10-K and Note (I) for additional information on energy-related derivative contracts. For the Three Months Ended September 30, 2018 For the Nine Months Ended September 30, 2018 (in millions) Southern Company Gas Operating revenues Natural gas distribution revenues Residential $ 149 $ 1,082 Commercial 45 313 Transportation 203 708 Industrial 4 28 Other 32 168 Alternative revenue programs (a) 5 (23 ) Total natural gas distribution revenues $ 438 $ 2,276 Gas marketing services (b) 44 403 Wholesale gas services (c) (10 ) 121 Gas midstream operations 20 60 Other revenues — 1 Total operating revenues $ 492 $ 2,861 (a) See Note 1 to the financial statements of Southern Company Gas under "Revenues" in Item 8 of the Form 10-K for additional information on alternative revenue programs at the natural gas distribution utilities. Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period. (b) Gas marketing services includes $4 million for the nine months ended September 30, 2018 of revenues not accounted for under ASC 606. (c) Wholesale gas services revenues are presented net of the related costs associated with its energy trading and risk management activities. Operating revenues, as presented, include gross third-party revenues of $1.6 billion and $4.8 billion for the three and nine months ended September 30, 2018 , respectively, of which $0.9 billion and $2.7 billion , respectively, relates to contracts that are accounted for as derivatives. See Note (L) under " Southern Company Gas " for additional information on the components of wholesale gas services operating revenues and Note (I) for additional information on energy-related derivative contracts. |
Contract with Customer, Asset and Liability | The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers as of September 30, 2018 : Receivables Contract Assets Contract Liabilities (in millions) Southern Company $ 2,778 $ 99 $ 34 Alabama Power 649 1 14 Georgia Power 924 70 3 Gulf Power 186 — — Mississippi Power 96 — — Southern Power 142 — 17 Southern Company Gas 523 — 1 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | Revenues from contracts with customers related to these performance obligations remaining at September 30, 2018 are expected to be recognized as follows: 2018 2019 2020 2021 2022 2023 and Thereafter (in millions) Southern Company (*) $ 168 $ 406 $ 322 $ 322 $ 310 $ 2,112 Alabama Power 6 22 22 26 23 161 Georgia Power 10 41 38 40 30 113 Gulf Power 5 22 — — — — Mississippi Power 1 3 3 1 — — Southern Power (*) 75 310 283 277 276 2,005 (*) Excludes amounts related to held for sale assets. See Note (J) under " Southern Company's Sale of Gulf Power " and " Southern Power – Sale of Florida Plants " for additional information. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Fair Value Disclosures [Abstract] | |
Assets and Liabilities Measured at Fair Value on a Recurring Basis | As of September 30, 2018 , 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: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Southern Company Assets: Energy-related derivatives (a)(b) $ 271 $ 150 $ — $ — $ 421 Foreign currency derivatives — 122 — — 122 Nuclear decommissioning trusts (c) 828 1,007 — 37 1,872 Non-qualified deferred compensation trusts: Domestic equity — 11 — — 11 Foreign equity — 6 — — 6 Pooled funds – fixed income — 13 — — 13 Cash equivalents 15 — — — 15 Other 9 — — — 9 Cash equivalents 1,309 — — — 1,309 Total $ 2,432 $ 1,309 $ — $ 37 $ 3,778 Liabilities: Energy-related derivatives (a)(b) $ 416 $ 159 $ — $ — $ 575 Interest rate derivatives — 72 — — 72 Foreign currency derivatives — 23 — — 23 Contingent consideration — — 22 — 22 Total $ 416 $ 254 $ 22 $ — $ 692 Fair Value Measurements Using: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Alabama Power Assets: Energy-related derivatives $ — $ 7 $ — $ — $ 7 Nuclear decommissioning trusts: (d) Domestic equity 469 89 — — 558 Foreign equity 60 56 — — 116 U.S. Treasury and government agency securities — 18 — — 18 Corporate bonds 26 154 — — 180 Mortgage and asset backed securities — 22 — — 22 Private equity — — — 37 37 Other 7 — — — 7 Cash equivalents 513 — — — 513 Total $ 1,075 $ 346 $ — $ 37 $ 1,458 Liabilities: Energy-related derivatives $ — $ 10 $ — $ — $ 10 Georgia Power Assets: Energy-related derivatives $ — $ 8 $ — $ — $ 8 Nuclear decommissioning trusts: (d)(e) Domestic equity 250 1 — — 251 Foreign equity — 134 — — 134 U.S. Treasury and government agency securities — 236 — — 236 Municipal bonds — 82 — — 82 Corporate bonds — 163 — — 163 Mortgage and asset backed securities — 42 — — 42 Other 16 9 — — 25 Cash equivalents 350 — — — 350 Total $ 616 $ 675 $ — $ — $ 1,291 Liabilities: Energy-related derivatives $ — $ 22 $ — $ — $ 22 Interest rate derivatives — 6 — — 6 Total $ — $ 28 $ — $ — $ 28 Gulf Power Assets: Cash equivalents $ 27 $ — $ — $ — $ 27 Liabilities: Energy-related derivatives $ — $ 8 $ — $ — $ 8 Fair Value Measurements Using: As of September 30, 2018: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Mississippi Power Assets: Energy-related derivatives $ — $ 3 $ — $ — $ 3 Cash equivalents 346 — — — 346 Total $ 346 $ 3 $ — $ — $ 349 Liabilities: Energy-related derivatives $ — $ 9 $ — $ — $ 9 Southern Power Assets: Energy-related derivatives $ — $ 3 $ — $ — $ 3 Foreign currency derivatives — 122 — — 122 Total $ — $ 125 $ — $ — $ 125 Liabilities: Energy-related derivatives $ — $ 7 $ — $ — $ 7 Foreign currency derivatives — 23 — — 23 Contingent consideration — — 22 — 22 Total $ — $ 30 $ 22 $ — $ 52 Southern Company Gas Assets: Energy-related derivatives (a)(b) $ 271 $ 129 $ — $ — $ 400 Non-qualified deferred compensation trusts: Domestic equity — 11 — — 11 Foreign equity — 6 — — 6 Pooled funds – fixed income — 13 — — 13 Cash equivalents 4 — — — 4 Cash equivalents 26 — — — 26 Total $ 301 $ 159 $ — $ — $ 460 Liabilities: Energy-related derivatives (a)(b) $ 416 $ 101 $ — $ — $ 517 (a) Excludes $5 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value. (b) Excludes cash collateral of $189 million . (c) For additional detail, see the nuclear decommissioning trusts sections for Alabama Power and Georgia Power in this table. (d) Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. (e) Includes the investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. As of September 30, 2018 , approximately $37 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. |
Schedule of Increase (Decrease) In Fair Value Of Funds | The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased for the three and nine months ended September 30, 2018 and 2017 by the amounts shown in the table below. The increases were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively. Three Months Ended September 30, 2018 Three Months Ended September 30, 2017 Nine Months Ended September 30, 2018 Nine Months Ended September 30, 2017 (in millions) Southern Company $ 58 $ 50 $ 68 $ 168 Alabama Power 39 25 49 87 Georgia Power 19 25 19 81 |
Fair Value Measurements of Investments Calculated at Net Asset Value per Share as Well as the Nature and Risk of Those Investments | As of September 30, 2018 , the fair value measurements of private equity investments held in the nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient, as well as the nature and risks of those investments, were as follows: As of September 30, 2018: Fair Value Unfunded Commitments (in millions) Southern Company $ 37 $ 47 Alabama Power $ 37 $ 47 |
Financial Instruments for Which Carrying Amount Did Not Equal Fair Value | As of September 30, 2018 , other financial instruments for which the carrying amount did not equal fair value were as follows: Carrying Amount Fair Value (in millions) Long-term debt, including securities due within one year: Southern Company $ 45,524 $ 45,500 Alabama Power 8,120 8,321 Georgia Power 10,227 10,159 Gulf Power 1,285 1,290 Mississippi Power 1,736 1,702 Southern Power 5,029 5,058 Southern Company Gas 5,908 5,935 |
Stockholders' Equity (Tables)
Stockholders' Equity (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Equity [Abstract] | |
Earnings per Share | Shares used to compute diluted earnings per share were as follows: Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended (in millions) As reported shares 1,023 1,003 1,016 998 Effect of stock-based compensation 6 7 5 7 Diluted shares 1,029 1,010 1,021 1,005 |
Changes in Stockholders' Equity | The following table presents year-to-date changes in stockholders' equity of Southern Company: Number of Common Shares Common Preferred and Preference Stock of Subsidiaries Total Issued Treasury Noncontrolling Interests (a) (in thousands) (in millions) Balance at December 31, 2017 1,008,532 (929 ) $ 24,167 $ — $ 1,361 $ 25,528 Consolidated net income attributable to Southern Company — — 1,948 — — 1,948 Other comprehensive income — — 52 — — 52 Stock issued 21,342 — 878 — — 878 Stock-based compensation — — 74 — — 74 Cash dividends on common stock — — (1,805 ) — — (1,805 ) Contributions from noncontrolling interests — — — — 154 154 Distributions to noncontrolling interests — — — — (87 ) (87 ) Net income attributable to noncontrolling interests — — — — 71 71 Sale of noncontrolling interests (b) — — (410 ) — 1,690 1,280 Other — (57 ) (27 ) — (1 ) (28 ) Balance at September 30, 2018 1,029,874 (986 ) $ 24,877 $ — $ 3,188 $ 28,065 Balance at December 31, 2016 991,213 (819 ) $ 24,758 $ 609 $ 1,245 $ 26,612 Consolidated net income attributable to Southern Company — — 347 — — 347 Other comprehensive income (loss) — — (2 ) — — (2 ) Stock issued 13,308 — 613 — — 613 Stock-based compensation — — 97 — — 97 Cash dividends on common stock — — (1,716 ) — — (1,716 ) Preference stock redemption — — — (150 ) — (150 ) Contributions from noncontrolling interests — — — — 77 77 Distributions to noncontrolling interests — — — — (87 ) (87 ) Net income attributable to noncontrolling interests — — — — 45 45 Reclassification from redeemable noncontrolling interests — — — — 114 114 Other — (75 ) (15 ) 3 1 (11 ) Balance at September 30, 2017 1,004,521 (894 ) $ 24,082 $ 462 $ 1,395 $ 25,939 (a) Primarily related to Southern Power and excludes redeemable noncontrolling interests. See Note 10 to the financial statements of Southern Power in Item 8 of the Form 10-K for additional information. (b) See Note (J) under "Southern Power – Sale of Solar Facility Interests " for additional information. |
Financing (Tables)
Financing (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Debt Disclosure [Abstract] | |
Credit Arrangements by Company | The following table outlines the committed credit arrangements by company as of September 30, 2018 : Expires Executable Term Loans Expires Within One Year Company 2018 2019 2020 2022 Total Unused One Year Term Out No Term Out (in millions) Southern Company (a) $ — $ — $ — $ 2,000 $ 2,000 $ 1,999 $ — $ — $ — Alabama Power — 33 500 800 1,333 1,333 — — 33 Georgia Power — — — 1,750 1,750 1,736 — — — Gulf Power 20 25 235 — 280 280 45 45 — Mississippi Power — 100 — — 100 100 — — — Southern Power Company (b) — — — 750 750 728 — — — Southern Company Gas (c) — — — 1,900 1,900 1,895 — — — Other — 30 — — 30 30 — — 30 Southern Company Consolidated $ 20 $ 188 $ 735 $ 7,200 $ 8,143 $ 8,101 $ 45 $ 45 $ 63 (a) Represents the Southern Company parent entity. (b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2019, of which $22 million remains unused at September 30, 2018 . (c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of these arrangements. Southern Company Gas' committed credit arrangements also include $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. |
Schedule of Long-term Debt Financing Activities | The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first nine months of 2018 : Company Senior Note Issuances Senior Note Maturities, Redemptions, and Repurchases Revenue Bond Other Long-Term Debt Issuances Other Long-Term Debt Redemptions and Maturities (a) (in millions) Southern Company (b) $ 750 $ 1,000 $ — $ — $ — Alabama Power 500 — — — — Georgia Power — 1,000 469 — 107 Mississippi Power 600 — 43 — 900 Southern Power — 350 — — 420 Southern Company Gas — — 200 100 — Other — — — — 10 Elimination (c) — — — — (1 ) Southern Company Consolidated $ 1,850 $ 2,350 $ 712 $ 100 $ 1,436 (a) Includes reductions in capital lease obligations resulting from cash payments under capital leases. (b) Represents the Southern Company parent entity. (c) Represents reductions in affiliate capital lease obligations at Georgia Power, which are eliminated in Southern Company's Consolidated Financial Statements. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Retirement Benefits [Abstract] | |
Pension Plans and Postretirement Plans | Components of the net periodic benefit costs for the three and nine months ended September 30, 2018 and 2017 are presented in the following tables. Three Months Ended September 30, 2018 Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Power Southern Company Gas (in millions) Pension Plans Service cost $ 90 $ 19 $ 22 $ 4 $ 5 $ 3 $ 8 Interest cost 116 26 34 5 5 1 10 Expected return on plan assets (236 ) (51 ) (74 ) (10 ) (11 ) (3 ) (18 ) Amortization: Prior service costs 1 — 1 — — — (1 ) Regulatory asset — — — — — — 4 Net (gain)/loss 53 13 18 2 3 — 3 Net periodic pension cost (income) $ 24 $ 7 $ 1 $ 1 $ 2 $ 1 $ 6 Postretirement Benefits Service cost $ 6 $ 1 $ 2 $ — $ — $ 1 $ — Interest cost 19 5 7 1 — — 2 Expected return on plan assets (17 ) (7 ) (6 ) — — — (1 ) Amortization: Prior service costs 2 1 — — — — — Regulatory asset — — — — — — 2 Net (gain)/loss 3 — 2 — — — — Net periodic postretirement benefit cost $ 13 $ — $ 5 $ 1 $ — $ 1 $ 3 Nine Months Ended September 30, 2018 Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Power Southern Company Gas (in millions) Pension Plans Service cost $ 269 $ 58 $ 65 $ 12 $ 13 $ 7 $ 24 Interest cost 348 76 104 15 15 4 29 Expected return on plan assets (707 ) (155 ) (222 ) (30 ) (31 ) (8 ) (53 ) Amortization: Prior service costs 3 1 2 — — — (2 ) Regulatory asset — — — — — — 11 Net (gain)/loss 160 40 52 7 8 1 9 Net periodic pension cost (income) $ 73 $ 20 $ 1 $ 4 $ 5 $ 4 $ 18 Postretirement Benefits Service cost $ 18 $ 4 $ 5 $ 1 $ 1 $ 1 $ 1 Interest cost 56 13 21 2 2 — 7 Expected return on plan assets (51 ) (20 ) (19 ) (1 ) (1 ) — (5 ) Amortization: Prior service costs 5 3 1 — — — — Regulatory asset — — — — — — 5 Net (gain)/loss 10 1 6 — — — — Net periodic postretirement benefit cost $ 38 $ 1 $ 14 $ 2 $ 2 $ 1 $ 8 Three Months Ended September 30, 2017 (*) Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (in millions) Pension Plans Service cost $ 73 $ 15 $ 19 $ 3 $ 4 $ 6 Interest cost 114 25 34 5 5 10 Expected return on plan assets (224 ) (49 ) (71 ) (10 ) (9 ) (18 ) Amortization: Prior service costs 3 1 — — — — Net (gain)/loss 41 10 15 2 1 5 Net periodic pension cost (income) $ 7 $ 2 $ (3 ) $ — $ 1 $ 3 Postretirement Benefits Service cost $ 6 $ 1 $ 2 $ — $ — $ 1 Interest cost 19 4 6 1 1 3 Expected return on plan assets (16 ) (5 ) (6 ) — — (2 ) Amortization: Prior service costs 2 1 — — — (1 ) Net (gain)/loss 3 — 3 — — 1 Net periodic postretirement benefit cost $ 14 $ 1 $ 5 $ 1 $ 1 $ 2 (*) Excludes Southern Power since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017. Nine Months Ended September 30, 2017 (*) Southern Company Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (in millions) Pension Plans Service cost $ 220 $ 47 $ 56 $ 10 $ 11 $ 17 Interest cost 341 73 103 15 15 30 Expected return on plan assets (673 ) (147 ) (212 ) (29 ) (29 ) (53 ) Amortization: Prior service costs 9 2 2 — 1 (1 ) Net (gain)/loss 122 31 43 5 5 15 Net periodic pension cost (income) $ 19 $ 6 $ (8 ) $ 1 $ 3 $ 8 Postretirement Benefits Service cost $ 18 $ 4 $ 5 $ 1 $ 1 $ 2 Interest cost 59 13 21 2 3 8 Expected return on plan assets (49 ) (19 ) (18 ) (1 ) (1 ) (5 ) Amortization: Prior service costs 5 3 1 — — (2 ) Net (gain)/loss 10 1 6 — — 3 Net periodic postretirement benefit cost $ 43 $ 2 $ 15 $ 2 $ 3 $ 6 (*) Excludes Southern Power since Southern Power did not participate in the qualified pension and postretirement benefit plans until December 2017. |
Income Taxes (Tables)
Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Income Tax Disclosure [Abstract] | |
Summary of Valuation Allowances | Valuation Allowances Georgia Power Mississippi Power Southern Company Gas Southern Company (in millions) Federal $ 6 $ — $ 11 $ 19 State (net of federal benefit) 33 124 1 171 Balance at September 30, 2018 $ 39 $ 124 $ 12 $ 190 |
Derivatives (Tables)
Derivatives (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Schedule of Energy-Related Derivatives | At September 30, 2018 , the net volume of energy-related derivative contracts for natural gas positions for the Southern Company system, 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 (*) 595 2022 2029 Alabama Power 82 2022 — Georgia Power 165 2022 — Gulf Power 9 2020 — Mississippi Power 69 2022 — Southern Power 15 2020 — Southern Company Gas (*) 255 2021 2029 (*) Southern Company's and 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 4.3 billion mmBtu and short natural gas positions of 4 billion mmBtu as of September 30, 2018 , which is also included in Southern Company's total volume. |
Schedule of Interest Rate Derivatives | At September 30, 2018 , the following interest rate derivatives were outstanding: Notional Amount Interest Rate Received Weighted Average Interest Rate Paid Hedge Maturity Date Fair Value Gain (Loss) at September 30, 2018 (in millions) (in millions) Fair Value Hedges of Existing Debt Southern Company (*) $ 300 2.75% 3-month June 2020 $ (6 ) Southern Company (*) 1,500 2.35% 1-month July 2021 (60 ) Georgia Power 500 1.95% 3-month December 2018 (3 ) Georgia Power 200 4.25% 3-month December 2019 (3 ) Southern Company Consolidated $ 2,500 $ (72 ) (*) Represents the Southern Company parent entity. |
Schedule of Foreign Currency Derivatives | At September 30, 2018 , the following foreign currency derivatives were outstanding: Pay Notional Pay Rate Receive Notional Receive Rate Hedge Fair Value Gain (Loss) at September 30, 2018 (in millions) (in millions) (in millions) Cash Flow Hedges of Existing Debt Southern Power $ 677 2.95% € 600 1.00% June 2022 $ 48 Southern Power 564 3.78% 500 1.85% June 2026 51 Total $ 1,241 € 1,100 $ 99 |
Fair Value of Energy-Related Derivatives and Interest Rate Derivatives | The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows: As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Southern Company Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 15 $ 17 $ 10 $ 43 Other deferred charges and assets/Other deferred credits and liabilities 5 26 7 24 Assets held for sale, current/Liabilities held for sale, current — 6 — — Assets held for sale/Liabilities held for sale — 2 — — Total derivatives designated as hedging instruments for regulatory purposes $ 20 $ 51 $ 17 $ 67 Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Other current assets/Other current liabilities $ 3 $ 6 $ 3 $ 14 Other deferred charges and assets/Other deferred credits and liabilities 1 1 — — Interest rate derivatives: Other current assets/Other current liabilities — 22 1 4 Other deferred charges and assets/Other deferred credits and liabilities — 50 — 34 Foreign currency derivatives: Other current assets/Other current liabilities — 23 — 23 Other deferred charges and assets/Other deferred credits and liabilities 122 — 129 — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ 126 $ 102 $ 133 $ 75 Derivatives not designated as hedging instruments Energy-related derivatives: Other current assets/Other current liabilities $ 263 $ 317 $ 380 $ 437 Other deferred charges and assets/Other deferred credits and liabilities 134 198 170 215 Total derivatives not designated as hedging instruments $ 397 $ 515 $ 550 $ 652 Gross amounts recognized $ 543 $ 668 $ 700 $ 794 Gross amounts offset (a) $ (303 ) $ (491 ) $ (405 ) $ (598 ) Net amounts recognized in the Balance Sheets (b) $ 240 $ 177 $ 295 $ 196 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Alabama Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 5 $ 4 $ 2 $ 6 Other deferred charges and assets/Other deferred credits and liabilities 2 6 2 4 Total derivatives designated as hedging instruments for regulatory purposes $ 7 $ 10 $ 4 $ 10 Gross amounts recognized $ 7 $ 10 $ 4 $ 10 Gross amounts offset $ (4 ) $ (4 ) $ (4 ) $ (4 ) Net amounts recognized in the Balance Sheets $ 3 $ 6 $ — $ 6 Georgia Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 5 $ 9 $ 2 $ 9 Other deferred charges and assets/Other deferred credits and liabilities 2 13 4 10 Total derivatives designated as hedging instruments for regulatory purposes $ 7 $ 22 $ 6 $ 19 Derivatives designated as hedging instruments in cash flow and fair value hedges Interest rate derivatives: Other current assets/Other current liabilities $ — $ 5 $ — $ 4 Other deferred charges and assets/Other deferred credits and liabilities — 1 — 1 Total derivatives designated as hedging instruments in cash flow and fair value hedges $ — $ 6 $ — $ 5 Gross amounts recognized $ 7 $ 28 $ 6 $ 24 Gross amounts offset $ (7 ) $ (7 ) $ (6 ) $ (6 ) Net amounts recognized in the Balance Sheets $ — $ 21 $ — $ 18 Gulf Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ — $ 6 $ — $ 14 Other deferred charges and assets/Other deferred credits and liabilities — 2 — 7 Total derivatives designated as hedging instruments for regulatory purposes $ — $ 8 $ — $ 21 Gross amounts recognized $ — $ 8 $ — $ 21 Net amounts recognized in the Balance Sheets $ — $ 8 $ — $ 21 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Mississippi Power Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Other current assets/Other current liabilities $ 2 $ 3 $ 1 $ 6 Other deferred charges and assets/Other deferred credits and liabilities 1 6 1 3 Total derivatives designated as hedging instruments for regulatory purposes $ 3 $ 9 $ 2 $ 9 Derivatives designated as hedging instruments in cash flow and fair value hedges Interest rate derivatives: Other current assets/Other current liabilities $ — $ — $ 1 $ — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ — $ — $ 1 $ — Gross amounts recognized $ 3 $ 9 $ 3 $ 9 Gross amounts offset $ (3 ) $ (3 ) $ (2 ) $ (2 ) Net amounts recognized in the Balance Sheets $ — $ 6 $ 1 $ 7 Southern Power Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Other current assets/Other current liabilities $ 2 $ 6 $ 3 $ 11 Other deferred charges and assets/Other deferred credits and liabilities 1 1 — — Foreign currency derivatives: Other current assets/Other current liabilities — 23 — 23 Other deferred charges and assets/Other deferred credits and liabilities 122 — 129 — Total derivatives designated as hedging instruments in cash flow and fair value hedges $ 125 $ 30 $ 132 $ 34 Derivatives not designated as hedging instruments Energy-related derivatives: Other current assets/Other current liabilities $ — $ — $ — $ 2 Gross amounts recognized $ 125 $ 30 $ 132 $ 36 Gross amounts offset $ (2 ) $ (2 ) $ (3 ) $ (3 ) Net amounts recognized in the Balance Sheets $ 123 $ 28 $ 129 $ 33 As of September 30, 2018 As of December 31, 2017 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) (in millions) Southern Company Gas Derivatives designated as hedging instruments for regulatory purposes Energy-related derivatives: Assets from risk management activities/Liabilities from risk management activities-current $ 3 $ 1 $ 5 $ 8 Other deferred charges and assets/Other deferred credits and liabilities — 1 — — Total derivatives designated as hedging instruments for regulatory purposes $ 3 $ 2 $ 5 $ 8 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-current $ 1 $ — $ — $ 3 Derivatives not designated as hedging instruments Energy-related derivatives: Assets from risk management activities/Liabilities from risk management activities-current $ 262 $ 316 $ 379 $ 434 Other deferred charges and assets/Other deferred credits and liabilities 134 198 170 215 Total derivatives not designated as hedging instruments $ 396 $ 514 $ 549 $ 649 Gross amounts of recognized $ 400 $ 516 $ 554 $ 660 Gross amounts offset (a) $ (287 ) $ (475 ) $ (390 ) $ (583 ) Net amounts recognized in the Balance Sheets (b) $ 113 $ 41 $ 164 $ 77 (a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $189 million and $193 million as of September 30, 2018 and December 31, 2017 , respectively. (b) Net amounts of derivative instruments outstanding exclude premium and intrinsic value associated with weather derivatives of $5 million and $11 million as of September 30, 2018 and December 31, 2017 , respectively. |
Pre-tax Effects of Unrealized Derivative Gains (Losses) Arising from Energy-Related Derivative Instruments | At September 30, 2018 and December 31, 2017 , 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 Sheet at September 30, 2018 Derivative Category and Balance Sheet Location Southern Company (*) Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (*) (in millions) Energy-related derivatives: Other regulatory assets, current $ (9 ) $ (2 ) $ (4 ) $ (6 ) $ (2 ) $ (1 ) Other regulatory assets, deferred (20 ) (4 ) (11 ) (2 ) (5 ) — Assets held for sale, current (6 ) — — — — — Assets held for sale (2 ) — — — — — Other regulatory liabilities, current 8 3 — — — 5 Total energy-related derivative gains (losses) $ (29 ) $ (3 ) $ (15 ) $ (8 ) $ (7 ) $ 4 (*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $3 million at September 30, 2018 . Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet at December 31, 2017 Derivative Category and Balance Sheet Location Southern Company (*) Alabama Power Georgia Power Gulf Power Mississippi Power Southern Company Gas (*) (in millions) Energy-related derivatives: Other regulatory assets, current $ (34 ) $ (4 ) $ (7 ) $ (14 ) $ (5 ) $ (4 ) Other regulatory assets, deferred (18 ) (3 ) (6 ) (7 ) (2 ) — Other regulatory liabilities, current 7 — — — — 7 Other regulatory liabilities, deferred 1 1 — — — — Total energy-related derivative gains (losses) $ (44 ) $ (6 ) $ (13 ) $ (21 ) $ (7 ) $ 3 (*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $6 million at December 31, 2017 . |
Pre-tax Effects of Interest Rate Derivatives, Designated as Cash Flow Hedging Instruments | For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of cash flow hedge accounting on accumulated OCI were as follows: Gain (Loss) Recognized in OCI on Derivative For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Company Energy-related derivatives $ (5 ) $ (6 ) $ 7 $ (26 ) Interest rate derivatives — (1 ) (2 ) (2 ) Foreign currency derivatives (10 ) 46 (31 ) 114 Total $ (15 ) $ 39 $ (26 ) $ 86 Southern Power Energy-related derivatives $ (5 ) $ (6 ) $ 5 $ (21 ) Foreign currency derivatives (10 ) 46 (31 ) 114 Total $ (15 ) $ 40 $ (26 ) $ 93 Southern Company Gas Energy-related derivatives $ — $ — $ 2 $ (4 ) |
Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location | For the three and nine months ended September 30, 2018 and 2017 , the pre-tax effects of cash flow and fair value hedge accounting on income were as follows: Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Company Cost of natural gas $ 104 $ 134 $ 1,053 $ 1,085 Gain (loss) on cash flow hedges (a) Energy-related derivatives — — (2 ) — Depreciation and amortization 787 767 2,338 2,236 Gain (loss) on cash flow hedges (a) Energy-related derivatives — (6 ) 2 (12 ) Interest expense, net of amounts capitalized (458 ) (407 ) (1,386 ) (1,248 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (5 ) (5 ) (16 ) (15 ) Foreign currency derivatives (6 ) (5 ) (18 ) (17 ) Gain (loss) on fair value hedges (b) Interest rate derivatives (4 ) (5 ) (35 ) (6 ) Other income (expense), net 57 65 195 165 Gain (loss) on cash flow hedges (a)(c) Foreign currency derivatives (9 ) 43 (46 ) 139 Alabama Power Interest expense, net of amounts capitalized $ (82 ) $ (76 ) $ (240 ) $ (229 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (1 ) (2 ) (4 ) (5 ) Georgia Power Interest expense, net of amounts capitalized $ (95 ) $ (105 ) $ (303 ) $ (310 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives (1 ) (1 ) (4 ) (3 ) Gain (loss) on fair value hedges (b) Interest rate derivatives — — (1 ) (1 ) Mississippi Power Interest expense, net of amounts capitalized $ (19 ) $ 13 $ (59 ) $ (23 ) Gain (loss) on cash flow hedges (a) Interest rate derivatives — — (1 ) (1 ) Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Southern Power Depreciation and amortization $ 130 $ 131 $ 370 $ 379 Gain (loss) on cash flow hedges (a) Energy-related derivatives — (6 ) 2 (12 ) Interest expense, net of amounts capitalized (45 ) (47 ) (138 ) (144 ) Gain (loss) on cash flow hedges (a) Foreign currency derivatives (6 ) (5 ) (18 ) (17 ) Other income (expense), net 17 3 22 3 Gain (loss) on cash flow hedges (a)(c) Foreign currency derivatives (9 ) 43 (46 ) 139 Southern Company Gas Cost of natural gas $ 104 $ 134 $ 1,053 $ 1,085 Gain (loss) on cash flow hedges (a) Energy-related derivatives — — (2 ) — (a) Amounts reflect gains or losses on cash flow hedges that were reclassified from accumulated OCI into income. (b) For fair value hedges presented above, generally changes in the fair value of the derivative contracts are equal to changes in the fair value of the underlying debt and have no material impact on income. (c) The reclassification from accumulated OCI 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. |
Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location | As of September 30, 2018 and December 31, 2017, 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 As of September 30, 2018 As of December 31, 2017 As of September 30, 2018 As of December 31, 2017 (in millions) (in millions) Southern Company Securities due within one year $ (499 ) $ (746 ) $ 1 $ 3 Long-term debt (2,526 ) (2,553 ) 65 35 Georgia Power Securities due within one year $ (499 ) $ (746 ) $ 1 $ 3 Long-term debt (497 ) (498 ) 2 1 |
Pre-tax Effect of Interest Rate and Energy Related Derivatives | For the three and nine months ended September 30, 2018 and 2017 , 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 were as follows: Gain (Loss) Three Months Ended September 30, Nine Months Ended Derivatives in Non-Designated Hedging Relationships Statements of Income Location 2018 2017 2018 2017 (in millions) (in millions) Energy-related derivatives: Natural gas revenues (*) $ (36 ) $ (17 ) $ (79 ) $ 48 Cost of natural gas 2 2 5 (2 ) Total derivatives in non-designated hedging relationships $ (34 ) $ (15 ) $ (74 ) $ 46 (*) Excludes gains (losses) recorded in natural gas revenues associated with weather derivatives of $15 million for the nine months ended September 30, 2017 and immaterial amounts for all other periods presented. |
Acquisitions and Dispositions (
Acquisitions and Dispositions (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Business Combinations [Abstract] | |
Schedule of Business Acquisitions | During the nine months ended September 30, 2018, one of Southern Power's wholly-owned subsidiaries acquired and completed construction of the Gaskell West 1 solar facility . Acquisition-related costs were expensed as incurred and were not material. Project Facility Resource Seller; Acquisition Date Approximate Nameplate Capacity ( MW ) Location Southern Power Percentage Ownership Actual COD PPA Contract Period Gaskell West 1 Solar Recurrent Energy Development Holdings, LLC January 26, 2018 20 Kern County, CA 100% of Class B (*) March 2018 20 years (*) Southern Power owns 100% of the class B membership interests under a tax equity partnership agreement. |
Schedule of Construction Projects | Project Facility Resource Approximate Nameplate Capacity ( MW ) Location Actual/Expected COD PPA Contract Period Cactus Flats (a) Wind 148 Concho County, TX July 2018 12-15 years Mankato Natural Gas 385 Mankato, MN First half 2019 20 years Wild Horse Mountain (b) Wind 100 Pushmataha County, OK Fourth quarter 2019 20 years Reading (c) Wind 200 Osage and Lyon Counties, KS Second quarter 2020 12 years (a) In July 2017, Southern Power purchased 100% of the Cactus Flats facility and commenced construction. In July 2018, the facility was placed in service and, in August 2018, Southern Power closed on a tax equity partnership agreement and owns 100% of the class B membership interests. (b) In May 2018, Southern Power purchased 100% of the Wild Horse Mountain facility and commenced construction. Southern Power may enter into a tax equity partnership agreement, in which case it would then own 100% of the class B membership interests. (c) In August 2018, Southern Power purchased 100% of the membership interests from the joint development arrangement with Renewable Energy Systems Americas, Inc. and commenced construction. Southern Power may enter into a tax equity partnership agreement, in which case it would then own 100% of the class B membership interests. |
Disposal Groups, Including Discontinued Operations | Gulf Power and the Florida Plants represent individually significant components of Southern Company and Southern Power, respectively; therefore, pre-tax profit for these components for the three and nine months ended September 30, 2018 and 2017 is presented below: For the Three Months For the Nine Months 2018 2017 2018 2017 (in millions) (in millions) Earnings before income taxes: Gulf Power $ 59 $ 103 $ 146 $ 199 Southern Power's Florida Plants $ 18 $ 11 $ 40 $ 28 The following table provides Southern Company's and Southern Power's major classes of assets and liabilities classified as held for sale at September 30, 2018 : Southern Company Southern Power (in millions) Assets Held for Sale: Current assets $ 407 $ 18 Total property, plant, and equipment 4,093 168 Other non-current assets 574 17 Total Assets Held for Sale $ 5,074 $ 203 Liabilities Held for Sale: Current liabilities $ 355 $ 4 Long-term debt 1,285 — Accumulated deferred income taxes 542 — Other non-current liabilities 1,008 — Total Liabilities Held for Sale $ 3,190 $ 4 |
Variable Interest Entity and _2
Variable Interest Entity and Equity Method Investments (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Regulated Operations [Abstract] | |
Equity Method Investments | The carrying amounts of Southern Company Gas' equity method investments as of September 30, 2018 and December 31, 2017 and related income from those investments for the three and nine -month periods ended September 30, 2018 and September 30, 2017 were as follows: Investment Balance September 30, 2018 December 31, 2017 (in millions) SNG $ 1,260 $ 1,262 Atlantic Coast Pipeline 73 41 PennEast Pipeline 70 57 Other 126 117 Total $ 1,529 $ 1,477 Selected financial information of SNG for the three and nine months ended September 30, 2018 and September 30, 2017 is as follows: Income Statement Information Three Months Ended September 30, 2018 Three Months Ended September 30, 2017 Nine Months Ended September 30, 2018 Nine Months Ended September 30, 2017 (in millions) Revenues $ 145 $ 146 $ 451 $ 445 Operating income $ 71 $ 71 $ 230 $ 218 Net income $ 58 $ 57 $ 190 $ 172 |
Schedule of Other Nonoperating Income, by Component | Earnings from Equity Method Investments Three Months Ended Three Months Ended Nine Months Ended Nine Months (in millions) SNG $ 29 $ 28 $ 95 $ 86 PennEast Pipeline 2 1 4 5 Atlantic Coast Pipeline 1 1 4 4 Other 2 2 5 5 Total $ 34 $ 32 $ 108 $ 100 |
Segment and Related Informati_2
Segment and Related Information (Tables) | 9 Months Ended |
Sep. 30, 2018 | |
Segment Reporting [Abstract] | |
Financial Data for Business Segments | Financial data for business segments and products and services for the three and nine months ended September 30, 2018 and 2017 was as follows: Electric Utilities Traditional Electric Operating Companies Southern Power Eliminations Total Southern Company Gas All Other Eliminations Consolidated (in millions) Three Months Ended September 30, 2018: Operating revenues $ 5,014 $ 635 $ (140 ) $ 5,509 $ 492 $ 202 $ (44 ) $ 6,159 Segment net income (loss) (a)(b)(c)(d) 1,148 92 — 1,240 46 (119 ) (3 ) 1,164 Nine Months Ended September 30, 2018: Operating revenues $ 13,117 $ 1,699 $ (360 ) $ 14,456 $ 2,861 $ 984 $ (143 ) $ 18,158 Segment net income (loss) (a)(b)(c)(d) 1,711 235 — 1,946 294 (292 ) — 1,948 At September 30, 2018: Goodwill $ — $ 2 $ — $ 2 $ 5,015 $ 298 $ — $ 5,315 Total assets 75,069 15,355 (322 ) 90,102 20,398 3,086 (1,869 ) 111,717 Three Months Ended September 30, 2017: Operating revenues $ 5,017 $ 618 $ (112 ) $ 5,523 $ 565 $ 153 $ (40 ) $ 6,201 Segment net income (loss) (a)(b) 1,008 124 — 1,132 15 (80 ) 2 1,069 Nine Months Ended September 30, 2017: Operating revenues $ 12,960 $ 1,597 $ (318 ) $ 14,239 $ 2,841 $ 442 $ (119 ) $ 17,403 Segment net income (loss) (a)(b)(e) — 276 — 276 303 (232 ) — 347 At December 31, 2017: Goodwill $ — $ 2 $ — $ 2 $ 5,967 $ 299 $ — $ 6,268 Total assets 72,204 15,206 (325 ) 87,085 22,987 2,552 (1,619 ) 111,005 (a) Attributable to Southern Company. (b) Segment net income (loss) for the traditional electric operating companies includes pre-tax charges for estimated losses on plants under construction of $1 million ( $1 million after tax) and $34 million ( $21 million after tax) for the three months ended September 30, 2018 and 2017 , respectively, and $1.1 billion ( $0.8 billion after tax) and $3.2 billion ( $2.2 billion after tax) for the nine months ended September 30, 2018 and 2017 , respectively. See Note 3 to the financial statements of Southern Company under "Kemper County Energy Facility" in Item 8 of the Form 10-K and Note (B) under " Nuclear Construction " and " Kemper County Energy Facility " for additional information. (c) Segment net income (loss) for Southern Power includes pre-tax impairment charges of $36 million ( $27 million after tax) and $155 million ( $116 million after tax) for the three and nine months ended September 30, 2018, respectively. See Note (J) under "Southern Power – Development Projects " and " – Sale of Florida Plants " for additional information. (d) Segment net income (loss) for Southern Company Gas includes a net gain on dispositions of $353 million ( $40 million gain after tax) and $317 million ( $35 million loss after tax) for the three and nine months ended September 30, 2018, respectively, related to the Southern Company Gas Dispositions and a goodwill impairment charge of $42 million for the nine months ended September 30, 2018 related to the sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas " for additional information. (e) Segment net income (loss) for the traditional electric operating companies includes a pre-tax charge for the write-down of Gulf Power's ownership of Plant Scherer Unit 3 of $33 million ( $20 million after tax) for the nine months ended September 30, 2017. See Note 3 to the financial statements of Southern Company under "Regulatory Matters – Gulf Power – Retail Base Rate Cases" in Item 8 of the Form 10-K for additional information. Business segment financial data for the three and nine months ended September 30, 2018 and 2017 was as follows: Gas Distribution Operations (a)(c) Gas Marketing Services (b)(c) Wholesale Gas Services (d) Gas Midstream Operations Total All Other Eliminations Consolidated (in millions) Three Months Ended September 30, 2018: Operating revenues $ 441 $ 44 $ (8 ) $ 20 $ 497 $ 1 $ (6 ) $ 492 Segment net income (loss) 74 (8 ) (18 ) 16 64 (18 ) — 46 Nine Months Ended September 30, 2018: Operating revenues 2,297 403 142 60 2,902 3 (44 ) 2,861 Segment net income (loss) 290 (71 ) 65 54 338 (44 ) — 294 Total assets at September 30, 2018: 16,850 1,522 855 2,297 21,524 10,146 (11,272 ) 20,398 Three Months Ended September 30, 2017: Operating revenues $ 472 $ 143 $ (24 ) $ 16 $ 607 $ 2 $ (44 ) $ 565 Segment net income (loss) 52 1 (23 ) 14 44 (29 ) — 15 Nine Months Ended September 30, 2017: Operating revenues 2,255 597 95 53 3,000 7 (166 ) 2,841 Segment net income (loss) 223 36 28 38 325 (22 ) — 303 Total assets at December 31, 2017: 19,358 2,147 1,096 2,241 24,842 12,184 (14,039 ) 22,987 (a) Operating revenues for the three gas distribution operations dispositions were $8 million and $50 million for the three months ended September 30, 2018 and 2017 , respectively, and $245 million and $274 million for the nine months ended September 30, 2018 and 2017 , respectively. See Note (J) under " Southern Company Gas " for additional information. (b) Operating revenues for the gas marketing services disposition were $32 million for the three months ended September 30, 2017 and $55 million and $95 million for the nine months ended September 30, 2018 and 2017 , respectively. See Note (J) under " Southern Company Gas " for additional information. (c) Segment net income for gas distribution operations includes a gain on dispositions of $351 million ( $38 million after tax) for the three and nine months ended September 30, 2018 . Segment net income for gas marketing services includes a gain on disposition of $2 million ( $2 million after tax) for the three months ended September 30, 2018 and a loss on disposition of $34 million ( $73 million loss after tax) and a goodwill impairment charge of $42 million for the nine months ended September 30, 2018 recorded in contemplation of the sale of Pivotal Home Solutions. See Note (J) under " Southern Company Gas " for additional information. (d) The revenues for wholesale gas services are 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) Three Months Ended September 30, 2018 $ 1,573 $ 82 $ 1,655 $ 1,663 $ (8 ) Three Months Ended September 30, 2017 1,411 103 1,514 1,538 (24 ) Nine Months Ended September 30, 2018 $ 4,847 $ 352 $ 5,199 $ 5,057 $ 142 Nine Months Ended September 30, 2017 4,781 362 5,143 5,048 95 |
Financial Data for Products and Services | Products and Services Electric Utilities' Revenues Period Retail Wholesale Other Total (in millions) Three Months Ended September 30, 2018 $ 4,605 $ 693 $ 211 $ 5,509 Three Months Ended September 30, 2017 4,615 718 190 5,523 Nine Months Ended September 30, 2018 $ 11,913 $ 1,923 $ 620 $ 14,456 Nine Months Ended September 30, 2017 11,786 1,867 586 14,239 Southern Company Gas' Revenues Period Gas Gas Other Total (in millions) Three Months Ended September 30, 2018 $ 438 $ 44 $ 10 $ 492 Three Months Ended September 30, 2017 430 143 (8 ) 565 Nine Months Ended September 30, 2018 $ 2,276 $ 403 $ 182 $ 2,861 Nine Months Ended September 30, 2017 2,119 597 125 2,841 |
Introduction - Narrative (Detai
Introduction - Narrative (Details) - USD ($) | 1 Months Ended | 3 Months Ended | 9 Months Ended | ||
Jun. 30, 2018 | Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Related Party Transaction [Line Items] | |||||
Net income (loss) | $ 1,222,000,000 | $ 1,109,000,000 | $ 2,031,000,000 | $ 427,000,000 | |
ALABAMA POWER CO | |||||
Related Party Transaction [Line Items] | |||||
Net income (loss) | 377,000,000 | 330,000,000 | $ 868,000,000 | 743,000,000 | |
Increase in ARO due to new CCR rule | $ 1,200,000,000 | ||||
Inflation rate assumption | 4.50% | ||||
Trust earnings rate assumption | 7.00% | ||||
MISSISSIPPI POWER CO | |||||
Related Party Transaction [Line Items] | |||||
Net income (loss) | 47,000,000 | 40,000,000 | $ 87,000,000 | (2,033,000,000) | |
Increase in ARO due to new CCR rule | 11,000,000 | ||||
SOUTHERN Co GAS | |||||
Related Party Transaction [Line Items] | |||||
Net income (loss) | 46,000,000 | 15,000,000 | 294,000,000 | 303,000,000 | |
Inventory decrement | 0 | 0 | |||
Wholesale Gas Services | SOUTHERN Co GAS | |||||
Related Party Transaction [Line Items] | |||||
Inventory write-down | 0 | $ 0 | 0 | $ 0 | |
Plant Farley | ALABAMA POWER CO | |||||
Related Party Transaction [Line Items] | |||||
Increase in ARO | $ 300,000,000 | ||||
Accounting Standards Update 2014-09 | Effect of Change | |||||
Related Party Transaction [Line Items] | |||||
Net income (loss) | (4,000,000) | 1,000,000 | |||
Accounting Standards Update 2014-09 | Effect of Change | SOUTHERN Co GAS | |||||
Related Party Transaction [Line Items] | |||||
Net income (loss) | $ (4,000,000) | $ 1,000,000 |
Introduction - ASC 606 (Details
Introduction - ASC 606 (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | Dec. 31, 2017 | |
Condensed Statements of Income | |||||
Total operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 | |
Other operations and maintenance | 1,404 | 1,341 | 4,217 | 4,100 | |
Operating income (loss) | 2,174 | 1,991 | 3,613 | 1,594 | |
Other income (expense), net | 57 | 65 | 195 | 165 | |
Earnings (loss) before income taxes | 1,845 | 1,699 | 2,629 | 744 | |
Income taxes (benefit) | 623 | 590 | 598 | 317 | |
Consolidated net income (loss) | 1,222 | 1,109 | 2,031 | 427 | |
Consolidated net income (loss) attributable to Southern Company | 1,164 | 1,069 | 1,948 | 347 | |
Condensed Statements of Cash Flows | |||||
Net income (loss) | 1,222 | 1,109 | 2,031 | 427 | |
Changes in certain current assets and liabilities: | |||||
Receivables | 37 | 423 | |||
Other current assets | (90) | (66) | |||
Other current liabilities | (67) | (129) | |||
Condensed Balance Sheets | |||||
Unbilled revenues | 738 | 738 | $ 810 | ||
Other accounts and notes receivable | 690 | 690 | 698 | ||
Other current assets | 232 | 232 | 199 | ||
Other current liabilities | 763 | 763 | 874 | ||
Retained earnings (accumulated deficit) | 9,048 | 9,048 | 8,885 | ||
Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 1,387 | 4,178 | |||
Operating income (loss) | 2,195 | 3,647 | |||
Other income (expense), net | 41 | 160 | |||
Earnings (loss) before income taxes | 1,850 | 2,628 | |||
Income taxes (benefit) | 624 | 598 | |||
Consolidated net income (loss) | 1,226 | 2,030 | |||
Consolidated net income (loss) attributable to Southern Company | 1,168 | 1,947 | |||
Condensed Statements of Cash Flows | |||||
Net income (loss) | 1,226 | 2,030 | |||
Changes in certain current assets and liabilities: | |||||
Receivables | 27 | ||||
Other current assets | (80) | ||||
Other current liabilities | (68) | ||||
Condensed Balance Sheets | |||||
Unbilled revenues | 776 | 776 | |||
Other accounts and notes receivable | 691 | 691 | |||
Other current assets | 193 | 193 | |||
Other current liabilities | 764 | 764 | |||
Retained earnings (accumulated deficit) | 9,047 | 9,047 | |||
ALABAMA POWER CO | |||||
Condensed Statements of Income | |||||
Total operating revenues | 1,740 | 1,740 | 4,716 | 4,606 | |
Other operations and maintenance | 401 | 406 | 1,191 | 1,177 | |
Operating income (loss) | 561 | 601 | 1,313 | 1,403 | |
Other income (expense), net | 9 | 10 | 24 | 35 | |
Earnings (loss) before income taxes | 504 | 546 | 1,140 | 1,236 | |
Income taxes (benefit) | 127 | 216 | 272 | 493 | |
Consolidated net income (loss) | 377 | 330 | 868 | 743 | |
Consolidated net income (loss) attributable to Southern Company | 373 | 325 | 857 | 729 | |
Condensed Statements of Cash Flows | |||||
Net income (loss) | 377 | 330 | 868 | 743 | |
Changes in certain current assets and liabilities: | |||||
Receivables | (207) | (163) | |||
Other current assets | 66 | 33 | |||
Other current liabilities | 60 | 7 | |||
Condensed Balance Sheets | |||||
Unbilled revenues | 159 | 159 | 162 | ||
Other accounts and notes receivable | 54 | 54 | 55 | ||
Other current assets | 8 | 8 | 5 | ||
Other current liabilities | 46 | 46 | 52 | ||
Retained earnings (accumulated deficit) | 2,902 | 2,902 | 2,647 | ||
ALABAMA POWER CO | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 390 | 1,159 | |||
Operating income (loss) | 563 | 1,319 | |||
Other income (expense), net | 7 | 18 | |||
GEORGIA POWER CO | |||||
Condensed Statements of Income | |||||
Total operating revenues | 2,593 | 2,546 | 6,601 | 6,426 | |
Other operations and maintenance | 460 | 430 | 1,325 | 1,248 | |
Operating income (loss) | 991 | 1,017 | 1,032 | 2,121 | |
Other income (expense), net | 30 | 22 | 104 | 95 | |
Earnings (loss) before income taxes | 926 | 934 | 833 | 1,906 | |
Income taxes (benefit) | 262 | 350 | 212 | 705 | |
Consolidated net income (loss) | 664 | 584 | 621 | 1,201 | |
Consolidated net income (loss) attributable to Southern Company | 664 | 580 | 621 | 1,188 | |
Condensed Statements of Cash Flows | |||||
Net income (loss) | 664 | 584 | 621 | 1,201 | |
Changes in certain current assets and liabilities: | |||||
Receivables | (205) | (254) | |||
Other current assets | (36) | (24) | |||
Other current liabilities | (111) | (11) | |||
Condensed Balance Sheets | |||||
Unbilled revenues | 245 | 245 | 255 | ||
Other accounts and notes receivable | 96 | 96 | 76 | ||
Other current assets | 91 | 91 | 14 | ||
Other current liabilities | 180 | 180 | 198 | ||
Retained earnings (accumulated deficit) | 3,792 | 3,792 | 4,215 | ||
GEORGIA POWER CO | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 437 | 1,268 | |||
Operating income (loss) | 990 | 1,027 | |||
Other income (expense), net | 31 | 109 | |||
Changes in certain current assets and liabilities: | |||||
Receivables | (242) | ||||
Other current assets | 1 | ||||
Condensed Balance Sheets | |||||
Unbilled revenues | 310 | 310 | |||
Other accounts and notes receivable | 97 | 97 | |||
Other current assets | 25 | 25 | |||
SOUTHERN Co GAS | |||||
Condensed Statements of Income | |||||
Total operating revenues | 492 | 565 | 2,861 | 2,841 | |
Other operations and maintenance | 216 | 206 | 730 | 675 | |
Operating income (loss) | 374 | 67 | 810 | 551 | |
Other income (expense), net | 6 | 19 | 21 | 30 | |
Earnings (loss) before income taxes | 362 | 67 | 769 | 536 | |
Income taxes (benefit) | 316 | 52 | 475 | 233 | |
Consolidated net income (loss) | 46 | 15 | 294 | 303 | |
Consolidated net income (loss) attributable to Southern Company | 46 | 15 | 294 | 303 | |
Condensed Statements of Cash Flows | |||||
Net income (loss) | 46 | 15 | 294 | 303 | |
Changes in certain current assets and liabilities: | |||||
Receivables | 445 | 531 | |||
Other current assets | 21 | (42) | |||
Other current liabilities | 35 | 8 | |||
Condensed Balance Sheets | |||||
Unbilled revenues | 58 | 58 | 285 | ||
Other accounts and notes receivable | 110 | 110 | 91 | ||
Other current assets | 88 | 88 | 78 | ||
Other current liabilities | 122 | 122 | 159 | ||
Retained earnings (accumulated deficit) | (273) | (273) | $ (212) | ||
SOUTHERN Co GAS | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Operating income (loss) | 379 | 809 | |||
Earnings (loss) before income taxes | 367 | 768 | |||
Income taxes (benefit) | 317 | 475 | |||
Consolidated net income (loss) | 50 | 293 | |||
Condensed Statements of Cash Flows | |||||
Net income (loss) | 50 | 293 | |||
Changes in certain current assets and liabilities: | |||||
Other current liabilities | 34 | ||||
Condensed Balance Sheets | |||||
Other current liabilities | 123 | 123 | |||
Retained earnings (accumulated deficit) | (274) | (274) | |||
SOUTHERN Co GAS | |||||
Condensed Statements of Income | |||||
Total operating revenues | 492 | 565 | 2,861 | 2,841 | |
Accounting Standards Update 2014-09 | Effect of Change | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 17 | 39 | |||
Operating income (loss) | (21) | (34) | |||
Other income (expense), net | 16 | 35 | |||
Earnings (loss) before income taxes | (5) | 1 | |||
Income taxes (benefit) | (1) | 0 | |||
Consolidated net income (loss) | (4) | 1 | |||
Consolidated net income (loss) attributable to Southern Company | (4) | 1 | |||
Condensed Statements of Cash Flows | |||||
Net income (loss) | (4) | 1 | |||
Changes in certain current assets and liabilities: | |||||
Receivables | 10 | ||||
Other current assets | (10) | ||||
Other current liabilities | 1 | ||||
Condensed Balance Sheets | |||||
Unbilled revenues | (38) | (38) | |||
Other accounts and notes receivable | (1) | (1) | |||
Other current assets | 39 | 39 | |||
Other current liabilities | (1) | (1) | |||
Retained earnings (accumulated deficit) | 1 | 1 | |||
Accounting Standards Update 2014-09 | ALABAMA POWER CO | Effect of Change | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 11 | 32 | |||
Operating income (loss) | (2) | (6) | |||
Other income (expense), net | 2 | 6 | |||
Accounting Standards Update 2014-09 | GEORGIA POWER CO | Effect of Change | |||||
Condensed Statements of Income | |||||
Other operations and maintenance | 23 | 57 | |||
Operating income (loss) | 1 | 5 | |||
Other income (expense), net | (1) | (5) | |||
Changes in certain current assets and liabilities: | |||||
Receivables | 37 | ||||
Other current assets | (37) | ||||
Condensed Balance Sheets | |||||
Unbilled revenues | (65) | (65) | |||
Other accounts and notes receivable | (1) | (1) | |||
Other current assets | 66 | 66 | |||
Accounting Standards Update 2014-09 | SOUTHERN Co GAS | Effect of Change | |||||
Condensed Statements of Income | |||||
Operating income (loss) | (5) | 1 | |||
Earnings (loss) before income taxes | (5) | 1 | |||
Income taxes (benefit) | (1) | 0 | |||
Consolidated net income (loss) | (4) | 1 | |||
Condensed Statements of Cash Flows | |||||
Net income (loss) | (4) | 1 | |||
Changes in certain current assets and liabilities: | |||||
Other current liabilities | 1 | ||||
Condensed Balance Sheets | |||||
Other current liabilities | (1) | (1) | |||
Retained earnings (accumulated deficit) | 1 | 1 | |||
Natural gas | |||||
Condensed Statements of Income | |||||
Total operating revenues | 492 | 532 | 2,806 | 2,746 | |
Natural gas | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Total operating revenues | 497 | 2,805 | |||
Natural gas | SOUTHERN Co GAS | |||||
Condensed Statements of Income | |||||
Total operating revenues | 487 | 532 | 2,829 | 2,737 | |
Natural gas | SOUTHERN Co GAS | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Total operating revenues | 492 | 2,828 | |||
Natural gas | Accounting Standards Update 2014-09 | Effect of Change | |||||
Condensed Statements of Income | |||||
Total operating revenues | (5) | 1 | |||
Natural gas | Accounting Standards Update 2014-09 | SOUTHERN Co GAS | Effect of Change | |||||
Condensed Statements of Income | |||||
Total operating revenues | (5) | 1 | |||
Other revenues | |||||
Condensed Statements of Income | |||||
Total operating revenues | 199 | 168 | 1,007 | 494 | |
Other revenues | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Total operating revenues | 198 | 1,003 | |||
Other revenues | ALABAMA POWER CO | |||||
Condensed Statements of Income | |||||
Total operating revenues | 68 | 50 | 199 | 158 | |
Other revenues | ALABAMA POWER CO | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Total operating revenues | 59 | 173 | |||
Other revenues | GEORGIA POWER CO | |||||
Condensed Statements of Income | |||||
Total operating revenues | 121 | 93 | 349 | 284 | |
Other revenues | GEORGIA POWER CO | Balances Without Adoption of ASC 606 | |||||
Condensed Statements of Income | |||||
Total operating revenues | 97 | 287 | |||
Other revenues | SOUTHERN Co GAS | |||||
Condensed Statements of Income | |||||
Total operating revenues | 0 | $ 33 | 55 | $ 95 | |
Other revenues | Accounting Standards Update 2014-09 | Effect of Change | |||||
Condensed Statements of Income | |||||
Total operating revenues | 1 | 4 | |||
Other revenues | Accounting Standards Update 2014-09 | ALABAMA POWER CO | Effect of Change | |||||
Condensed Statements of Income | |||||
Total operating revenues | 9 | 26 | |||
Other revenues | Accounting Standards Update 2014-09 | GEORGIA POWER CO | Effect of Change | |||||
Condensed Statements of Income | |||||
Total operating revenues | $ 24 | $ 62 |
Introduction - Asset Retirement
Introduction - Asset Retirement Obligation (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2018USD ($) | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance at December 31, 2017 | $ 4,824 |
Liabilities incurred | 2 |
Liabilities settled | (160) |
Accretion | 153 |
Cash flow revisions | 1,510 |
Reclassification to held for sale | (164) |
Balance at September 30, 2018 | 6,165 |
ALABAMA POWER CO | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance at December 31, 2017 | 1,709 |
Liabilities incurred | 0 |
Liabilities settled | (31) |
Accretion | 72 |
Cash flow revisions | 1,451 |
Reclassification to held for sale | 0 |
Balance at September 30, 2018 | 3,201 |
GEORGIA POWER CO | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance at December 31, 2017 | 2,638 |
Liabilities incurred | 0 |
Liabilities settled | (82) |
Accretion | 70 |
Cash flow revisions | (32) |
Reclassification to held for sale | 0 |
Balance at September 30, 2018 | 2,594 |
GULF POWER CO | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance at December 31, 2017 | 142 |
Liabilities incurred | 0 |
Liabilities settled | (23) |
Accretion | 3 |
Cash flow revisions | 42 |
Reclassification to held for sale | 0 |
Balance at September 30, 2018 | 164 |
MISSISSIPPI POWER CO | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance at December 31, 2017 | 174 |
Liabilities incurred | 0 |
Liabilities settled | (22) |
Accretion | 4 |
Cash flow revisions | 21 |
Reclassification to held for sale | 0 |
Balance at September 30, 2018 | $ 177 |
Introduction - Nuclear Decommis
Introduction - Nuclear Decommissioning (Details) - ALABAMA POWER CO - Plant Farley $ in Millions | 9 Months Ended |
Sep. 30, 2018USD ($) | |
Decommissioning periods: | |
Beginning year | 2,037 |
Completion year | 2,076 |
Site study costs | $ 1,720 |
Radiated structures | |
Decommissioning periods: | |
Site study costs | 1,621 |
Non-radiated structures | |
Decommissioning periods: | |
Site study costs | $ 99 |
Introduction - Goodwill (Detail
Introduction - Goodwill (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2018 | Mar. 31, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Goodwill [Roll Forward] | |||||
Balance at December 31, 2017 | $ 6,268 | $ 6,268 | |||
Impairment | (42) | ||||
Dispositions | (910) | ||||
Balance at September 30, 2018 | $ 5,315 | 5,315 | |||
SOUTHERN Co GAS | |||||
Goodwill [Roll Forward] | |||||
Balance at December 31, 2017 | 5,967 | 5,967 | |||
Impairment | 0 | (42) | $ 0 | (42) | $ 0 |
Dispositions | (910) | ||||
Balance at September 30, 2018 | 5,015 | 5,015 | |||
SOUTHERN Co GAS | Gas Distribution Operations | |||||
Goodwill [Roll Forward] | |||||
Balance at December 31, 2017 | 4,702 | 4,702 | |||
Impairment | 0 | ||||
Dispositions | (668) | ||||
Balance at September 30, 2018 | 4,034 | 4,034 | |||
SOUTHERN Co GAS | Gas Marketing Services | |||||
Goodwill [Roll Forward] | |||||
Balance at December 31, 2017 | $ 1,265 | 1,265 | |||
Impairment | (42) | ||||
Dispositions | (242) | ||||
Balance at September 30, 2018 | $ 981 | $ 981 |
Introduction - Other Intangible
Introduction - Other Intangible Assets Subject to Amortization (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Finite-Lived Intangible Assets [Line Items] | ||
Accumulated Amortization | $ (225) | $ (186) |
Total other intangible assets - net | 674 | 873 |
SOUTHERN POWER CO | ||
Finite-Lived Intangible Assets [Line Items] | ||
Accumulated Amortization | (66) | (47) |
SOUTHERN POWER CO | PPA fair value adjustments | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 456 | 456 |
Accumulated Amortization | (66) | (47) |
Other Intangible Assets, Net | 390 | 409 |
SOUTHERN Co GAS | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 246 | 400 |
Accumulated Amortization | (133) | (120) |
Other Intangible Assets, Net | 113 | 280 |
Total other intangible assets - net | 113 | 280 |
SOUTHERN Co GAS | Customer relationships | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 156 | 221 |
Accumulated Amortization | (78) | (77) |
Other Intangible Assets, Net | 78 | 144 |
SOUTHERN Co GAS | Trade names | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 26 | 115 |
Accumulated Amortization | (6) | (9) |
Other Intangible Assets, Net | 20 | 106 |
SOUTHERN Co GAS | Storage and transportation contracts | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 64 | 64 |
Accumulated Amortization | (49) | (34) |
Other Intangible Assets, Net | 15 | 30 |
Southern Company | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 824 | 984 |
Accumulated Amortization | (225) | (186) |
Other Intangible Assets, Net | 599 | 798 |
Total other intangible assets - gross | 899 | 1,059 |
Total other intangible assets - net | 674 | 873 |
Southern Company | Customer relationships | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 223 | 288 |
Accumulated Amortization | (87) | (83) |
Other Intangible Assets, Net | 136 | 205 |
Southern Company | Trade names | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 70 | 159 |
Accumulated Amortization | (18) | (17) |
Other Intangible Assets, Net | 52 | 142 |
Southern Company | Storage and transportation contracts | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 64 | 64 |
Accumulated Amortization | (49) | (34) |
Other Intangible Assets, Net | 15 | 30 |
Southern Company | PPA fair value adjustments | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 456 | 456 |
Accumulated Amortization | (66) | (47) |
Other Intangible Assets, Net | 390 | 409 |
Southern Company | Other | ||
Finite-Lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 11 | 17 |
Accumulated Amortization | (5) | (5) |
Other Intangible Assets, Net | $ 6 | $ 12 |
Introduction - Other Intangib_2
Introduction - Other Intangible Assets Not Subject to Amortization (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Indefinite-lived Intangible Assets [Line Items] | ||
Accumulated Amortization | $ (225) | $ (186) |
Total other intangible assets - net | 674 | 873 |
Southern Company | ||
Indefinite-lived Intangible Assets [Line Items] | ||
Total other intangible assets - gross | 899 | 1,059 |
Accumulated Amortization | (225) | (186) |
Total other intangible assets - net | 674 | 873 |
Federal Communications Commission licenses | Southern Company | ||
Indefinite-lived Intangible Assets [Line Items] | ||
Gross Carrying Amount | 75 | 75 |
SOUTHERN POWER CO | ||
Indefinite-lived Intangible Assets [Line Items] | ||
Accumulated Amortization | (66) | (47) |
SOUTHERN Co GAS | ||
Indefinite-lived Intangible Assets [Line Items] | ||
Accumulated Amortization | (133) | (120) |
Total other intangible assets - net | $ 113 | $ 280 |
Introduction - Intangibles, Amo
Introduction - Intangibles, Amortization (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended |
Sep. 30, 2018 | Sep. 30, 2018 | |
Finite-Lived Intangible Assets [Line Items] | ||
Amortization of intangible assets | $ 21 | $ 70 |
SOUTHERN POWER CO | ||
Finite-Lived Intangible Assets [Line Items] | ||
Amortization of intangible assets | 6 | 19 |
SOUTHERN Co GAS | ||
Finite-Lived Intangible Assets [Line Items] | ||
Amortization of intangible assets | $ 12 | $ 42 |
Introduction - Restricted Cash
Introduction - Restricted Cash (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Dec. 31, 2016 |
Restricted Cash and Cash Equivalents Items [Line Items] | ||||
Cash and cash equivalents | $ 1,847 | $ 2,130 | ||
Restricted cash: | ||||
Total cash, cash equivalents, and restricted cash | 1,891 | 2,147 | $ 1,858 | $ 1,992 |
SOUTHERN POWER CO | ||||
Restricted Cash and Cash Equivalents Items [Line Items] | ||||
Cash and cash equivalents | 192 | 129 | ||
Restricted cash: | ||||
Other accounts and notes receivable | 0 | |||
Deferred charges and other assets | 11 | |||
Total cash, cash equivalents, and restricted cash | 192 | 140 | 189 | 1,112 |
SOUTHERN Co GAS | ||||
Restricted Cash and Cash Equivalents Items [Line Items] | ||||
Cash and cash equivalents | 56 | 73 | ||
Cash and cash equivalents classified as assets held for sale | 0 | |||
Restricted cash: | ||||
Other accounts and notes receivable | 6 | 5 | ||
Deferred charges and other assets | 0 | |||
Total cash, cash equivalents, and restricted cash | 62 | 78 | $ 26 | $ 24 |
Southern Company | ||||
Restricted Cash and Cash Equivalents Items [Line Items] | ||||
Cash and cash equivalents | 1,847 | 2,130 | ||
Cash and cash equivalents classified as assets held for sale | 37 | |||
Restricted cash: | ||||
Other accounts and notes receivable | 6 | 5 | ||
Deferred charges and other assets | 12 | |||
Total cash, cash equivalents, and restricted cash | $ 1,891 | $ 2,147 |
Contingencies and Regulatory _3
Contingencies and Regulatory Matters - General Litigation Matters (Details) $ in Thousands | May 18, 2018USD ($) | May 04, 2018 | Apr. 25, 2018 | Mar. 02, 2018USD ($)generating_plant | Feb. 07, 2018 | Sep. 30, 2018USD ($) | Dec. 31, 2017USD ($) |
ALABAMA POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Public utilities, approved return on equity percentage | 47.00% | ||||||
MISSISSIPPI POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Public utilities, requested return on equity, percentage | 9.33% | ||||||
MISSISSIPPI POWER CO | MRA Fuel Costs | |||||||
Loss Contingencies [Line Items] | |||||||
Over recovered fuel cost | $ 7,000 | $ 0 | |||||
MISSISSIPPI POWER CO | MB Fuel Costs | |||||||
Loss Contingencies [Line Items] | |||||||
Over recovered fuel cost | 0 | 0 | |||||
SOUTHERN Co GAS | |||||||
Loss Contingencies [Line Items] | |||||||
Environmental remediation liability | 294,000 | 388,000 | |||||
GEORGIA POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Environmental remediation liability | 25,000 | 22,000 | |||||
GULF POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Environmental remediation liability | 48,000 | 52,000 | |||||
Location One | SOUTHERN Co GAS | |||||||
Loss Contingencies [Line Items] | |||||||
Environmental remediation liability | $ 2,000 | ||||||
Location One | SOUTHERN Co GAS | Elizabethtown Gas | |||||||
Loss Contingencies [Line Items] | |||||||
Environmental remediation liability | $ 85,000 | ||||||
Alabama Department of Environmental Management (ADEM) | ALABAMA POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Litigation settlement, amount awarded to other party | $ 1,250 | ||||||
Number of electric generating plants | generating_plant | 5 | ||||||
Open Access Transmission Tariff | |||||||
Loss Contingencies [Line Items] | |||||||
Public utilities, approved return on equity percentage | 11.25% | ||||||
RE Roserock, LLC | RE Roserock, LLC | SOUTHERN POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Ownership percentage by parent | 51.00% | ||||||
Maximum | Open Access Transmission Tariff | |||||||
Loss Contingencies [Line Items] | |||||||
Public utilities, requested return on equity, percentage | 8.65% | ||||||
Martin Product Sales, LLC Litigation | MISSISSIPPI POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Damages sought by litigation | $ 143,000 | ||||||
Deepwater Horizon Oil Spill Litigation Case | MISSISSIPPI POWER CO | |||||||
Loss Contingencies [Line Items] | |||||||
Litigation settlement awarded from other party | $ 18,000 | ||||||
Nicor Energy Services Company Litigation | SOUTHERN Co GAS | |||||||
Loss Contingencies [Line Items] | |||||||
Litigation amount awarded to other party | $ 11,000 | ||||||
Pending Litigation | Shareholder Derivative Lawsuits | |||||||
Loss Contingencies [Line Items] | |||||||
Stay period | 30 days | 30 days |
Contingencies and Regulatory _4
Contingencies and Regulatory Matters - Cost Recovery Clauses (Details) - ALABAMA POWER CO - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Under recovered regulatory clause revenues | ||
Loss Contingencies [Line Items] | ||
Rate CNP Compliance | $ 0 | $ 17 |
Rate CNP PPA | 30 | 12 |
Retail Energy Cost Recovery | 58 | 25 |
Under recovered regulatory clause revenues | ||
Loss Contingencies [Line Items] | ||
Rate CNP Compliance | 7 | 0 |
Retail Energy Cost Recovery | 41 | 0 |
Other regulatory liabilities, deferred | ||
Loss Contingencies [Line Items] | ||
Natural Disaster Reserve | $ 24 | $ 38 |
Contingencies and Regulatory _5
Contingencies and Regulatory Matters - Alabama Power (Details) | Aug. 06, 2018 | May 01, 2018USD ($)$ / KWH_Kilowatt_hour | Apr. 30, 2018$ / KWH_Kilowatt_hour | Jan. 31, 2019$ / KWH_Kilowatt_hour | Jun. 30, 2018 | Dec. 31, 2018USD ($) | Sep. 30, 2018USD ($) | Dec. 31, 2025 | Dec. 31, 2018USD ($) | Dec. 31, 2017 |
ALABAMA POWER CO | ||||||||||
Loss Contingencies [Line Items] | ||||||||||
Public utilities, approved return on equity percentage | 47.00% | |||||||||
Public utilities, allowed weighted common equity return, percentage | 6.15% | 6.21% | ||||||||
Customer refundable fees, refund payments, tranche one, percentage | 25.00% | |||||||||
Customer refundable fees, refund payments, tranche two, percentage | 40.00% | |||||||||
Customer refundable fees, refund payments, tranche three, percentage | 75.00% | |||||||||
Customer refund | $ 50,000,000 | |||||||||
Customer refundable fees, refund payments | 151,000,000 | |||||||||
Current billing rates under rate ecr in terms of per units | $ / KWH_Kilowatt_hour | 2.353 | 2.015 | ||||||||
Approved increase (decrease) in fuel rates amount | $ 100,000,000 | |||||||||
Tax Cuts and Jobs Act of 2017, change in tax rate, deferred tax liability, income tax benefit, maximum amount used to offset under recovered amounts | $ 30,000,000 | |||||||||
Tax Cuts and Jobs Act of 2017, change in tax rate, deferred tax liability, income tax benefit | $ 30,000,000 | |||||||||
ALABAMA POWER CO | Minimum | ||||||||||
Loss Contingencies [Line Items] | ||||||||||
Public utilities, actual weighted common equity return, threshold, percentage | 6.15% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche one | 6.15% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche two | 6.65% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche three | 7.15% | |||||||||
ALABAMA POWER CO | Maximum | ||||||||||
Loss Contingencies [Line Items] | ||||||||||
Public utilities, actual weighted common equity return, threshold, percentage | 7.65% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche one | 6.65% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche two | 7.15% | |||||||||
Public utilities, actual weighted common equity return, threshold for customer refundable fees, refund payments, percentage, tranche three | 7.65% | |||||||||
Customer refundable fees, refund payments, percentage | 7.65% | |||||||||
ALABAMA POWER CO | Scenario, Forecast | ||||||||||
Loss Contingencies [Line Items] | ||||||||||
Public utilities, approved return on equity percentage | 55.00% | |||||||||
Customer refundable fees, refund payments | $ 257,000,000 | |||||||||
Current billing rates under rate ecr in terms of per units | $ / KWH_Kilowatt_hour | 5.910 | |||||||||
Tax Cuts and Jobs Act of 2017, change in tax rate, deferred tax liability, income tax benefit | $ 50,000,000 | |||||||||
Reserve Margin Plan | Plant Greene County Units 1 and 2 | MISSISSIPPI POWER CO | ||||||||||
Loss Contingencies [Line Items] | ||||||||||
Accelerated retirement period | 4 years |
Contingencies and Regulatory _6
Contingencies and Regulatory Matters - Georgia Power (Details) $ in Millions | Apr. 03, 2018USD ($) | Feb. 29, 2020USD ($) | Jun. 30, 2019USD ($) | Oct. 31, 2018USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Dec. 31, 2019 | Dec. 31, 2017USD ($) |
Loss Contingencies [Line Items] | ||||||||
Effective tax rate | 22.70% | 42.60% | ||||||
Deferred income tax benefit | $ 286 | $ (15) | ||||||
GEORGIA POWER CO | ||||||||
Loss Contingencies [Line Items] | ||||||||
Customer refund | $ 330 | |||||||
Effective tax rate | 25.50% | 37.00% | ||||||
Deferred income tax benefit | $ 700 | $ 185 | $ (328) | |||||
Customer refund liability in absence of base rate case | $ 185 | |||||||
Retail regulatory equity ratio | 0.53 | |||||||
Under recovered fuel balance, threshold for interim fuel rider | $ 200 | |||||||
Annual accrual for incremental operating and maintenance costs of damage from major storms | 30 | |||||||
GEORGIA POWER CO | Storm Damage | ||||||||
Loss Contingencies [Line Items] | ||||||||
Regulatory asset | 311 | |||||||
GEORGIA POWER CO | Subsequent Event | ||||||||
Loss Contingencies [Line Items] | ||||||||
Customer refundable fees, refund payments | $ 130 | |||||||
GEORGIA POWER CO | Other current liabilities | ||||||||
Loss Contingencies [Line Items] | ||||||||
Under recovered fuel balance | 105 | $ 165 | ||||||
GEORGIA POWER CO | Maximum | ||||||||
Loss Contingencies [Line Items] | ||||||||
Retail regulatory equity ratio | 0.55 | |||||||
GEORGIA POWER CO | Maximum | Subsequent Event | Loss from Catastrophes | ||||||||
Loss Contingencies [Line Items] | ||||||||
Estimated restoration costs | 150 | |||||||
GEORGIA POWER CO | Minimum | Subsequent Event | Loss from Catastrophes | ||||||||
Loss Contingencies [Line Items] | ||||||||
Estimated restoration costs | $ 125 | |||||||
GEORGIA POWER CO | State (net of federal benefit) | ||||||||
Loss Contingencies [Line Items] | ||||||||
Effective tax rate | 6.00% | |||||||
GEORGIA POWER CO | Scenario, Forecast | ||||||||
Loss Contingencies [Line Items] | ||||||||
Customer refundable fees, refund payments | $ 105 | $ 95 | ||||||
GEORGIA POWER CO | Scenario, Forecast | State (net of federal benefit) | ||||||||
Loss Contingencies [Line Items] | ||||||||
Effective tax rate | 5.75% | |||||||
Impact of Tax Reform Legislation | GEORGIA POWER CO | ||||||||
Loss Contingencies [Line Items] | ||||||||
Regulatory liabilities | $ 655 |
Contingencies and Regulatory _7
Contingencies and Regulatory Matters - Gulf Power (Details) - GULF POWER CO $ in Millions | Nov. 05, 2018USD ($) | Oct. 30, 2018USD ($) | Oct. 10, 2018USD ($) | Mar. 26, 2018USD ($)intervenor | Mar. 25, 2018 | Sep. 30, 2018USD ($) | Dec. 31, 2017USD ($) |
Loss Contingencies [Line Items] | |||||||
Property damage reserve | $ 48 | ||||||
Property damage reserve replenishment | 40 | ||||||
Number of intervenors | intervenor | 3 | ||||||
Tax reform settlement agreement, annual reduction of revenue from base rates | $ 18.2 | ||||||
Tax reform settlement agreement, annual reduction of revenue from environmental cost recovery rates | 15.6 | ||||||
Tax reform settlement agreement, refund | $ 69.4 | ||||||
Customer refundable fees, refund payments | 53 | ||||||
Retail regulatory equity ratio | 0.535 | 0.525 | |||||
Environmental Cost Recovery | 21 | $ 11 | |||||
Projected environmental expenditures | 8 | 13 | |||||
Property Basis Differences | |||||||
Loss Contingencies [Line Items] | |||||||
Deferred tax asset, regulatory liability | 7 | ||||||
Subsequent Event | |||||||
Loss Contingencies [Line Items] | |||||||
Recovery from customers, period following the filing of cost recovery petition | 60 days | ||||||
Tax reform settlement agreement, annual reduction of revenue from base rates | $ 9.6 | ||||||
Decrease in annual revenues | $ 38 | ||||||
Under recovered regulatory clause revenues | |||||||
Loss Contingencies [Line Items] | |||||||
Fuel Cost Recovery | 0 | 22 | |||||
Purchased Power Capacity Recovery | 0 | 2 | |||||
Environmental Cost Recovery | 0 | 2 | |||||
Other regulatory liabilities, current | |||||||
Loss Contingencies [Line Items] | |||||||
Fuel Cost Recovery | 23 | 0 | |||||
Purchased Power Capacity Recovery | 4 | 0 | |||||
Environmental Cost Recovery | 13 | 0 | |||||
Energy Conservation Cost Recovery | $ 2 | $ 0 | |||||
Loss from Catastrophes | Subsequent Event | Minimum | |||||||
Loss Contingencies [Line Items] | |||||||
Estimated restoration costs | $ 350 | ||||||
Loss from Catastrophes | Subsequent Event | Maximum | |||||||
Loss Contingencies [Line Items] | |||||||
Estimated restoration costs | $ 400 |
Contingencies and Regulatory _8
Contingencies and Regulatory Matters - Mississippi Power (Details) - MISSISSIPPI POWER CO - USD ($) | Jul. 27, 2018 | May 08, 2018 | Mar. 22, 2018 | Feb. 07, 2018 | Sep. 30, 2018 | Sep. 30, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | Aug. 03, 2018 |
Loss Contingencies [Line Items] | ||||||||||||
Refund due to customers | $ 5,000,000 | |||||||||||
Performance evaluation plan, prior year lookback, surcharge (refund) | $ 0 | $ 5,000,000 | $ 5,000,000 | $ 0 | $ 0 | |||||||
Public utilities, interim rate increase (decrease), percentage | 4.00% | 0.00% | 0.00% | |||||||||
Public utilities, interim rate | $ 38,000,000 | |||||||||||
Public utilities, requested revenue requirement increase (decrease), amount | $ 26,000,000 | |||||||||||
Public utilities, requested return on equity, percentage | 9.33% | |||||||||||
Performance evaluation plan, equity ratio | 55.00% | |||||||||||
Increase retail base rate, annual base revenue | $ 3,000,000 | |||||||||||
Ad valorem tax adjustment, annual rate increase, percentage | 0.80% | |||||||||||
Ad valorem tax adjustment, annual rate increase, amount | $ 7,000,000 | |||||||||||
Environmental compliance overview plan, maximum annual increase in revenue, amount | $ 17,000,000 | |||||||||||
Over (under) recovered retail fuel costs | $ 13,000,000 | $ 13,000,000 | $ (6,000,000) | |||||||||
PEP Settlement Agreement | ||||||||||||
Loss Contingencies [Line Items] | ||||||||||||
Public utilities, approved revenue requirement increase (decrease), amount | $ 21,600,000 | |||||||||||
Amount subsequently approved for recovery | $ 2,000,000 | |||||||||||
Public utilities, performance-adjusted allowed return on equity percentage | 9.31% | |||||||||||
Public utilities, approved return on equity percentage | 45.00% | |||||||||||
Deferred income taxes | $ 44,000,000 | |||||||||||
Equity ratio, variance threshold | 1.00% | |||||||||||
Retail electric revenues | 5,000,000 | |||||||||||
PEP Settlement Agreement | Maximum | ||||||||||||
Loss Contingencies [Line Items] | ||||||||||||
Public utilities, approved return on equity percentage | 50.00% | |||||||||||
Other Regulatory Assets | PEP Settlement Agreement | ||||||||||||
Loss Contingencies [Line Items] | ||||||||||||
Regulatory asset | 3,000,000 | $ 3,000,000 | ||||||||||
Other Regulatory Assets | ||||||||||||
Loss Contingencies [Line Items] | ||||||||||||
Regulatory liabilities | 2,000,000 | 2,000,000 | ||||||||||
Other Regulatory Assets | PEP Settlement Agreement | ||||||||||||
Loss Contingencies [Line Items] | ||||||||||||
Regulatory liabilities | $ 5,000,000 | $ 5,000,000 |
Contingencies and Regulatory _9
Contingencies and Regulatory Matters - Southern Company Gas (Details) - USD ($) $ in Millions | Oct. 25, 2018 | Oct. 15, 2018 | May 15, 2018 | May 02, 2018 | Feb. 23, 2018 | Oct. 31, 2018 | Jul. 31, 2018 | Mar. 31, 2018 | Sep. 30, 2018 |
Florida City Gas | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, interim rate increase (decrease), percentage | 4.00% | ||||||||
Public utilities, approved return on equity percentage | 55.00% | ||||||||
Atlanta Gas Light | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, requested rate increase (decrease), amount | $ (16) | ||||||||
Customer credit | $ 8 | ||||||||
Atlanta Gas Light | Pipeline Replacement Program | |||||||||
Loss Contingencies [Line Items] | |||||||||
Litigation settlement awarded from other party | $ 7 | ||||||||
Atlanta Gas Light | Subsequent Event | |||||||||
Loss Contingencies [Line Items] | |||||||||
Customer credit | $ 8 | ||||||||
Nicor Gas | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, approved return on equity percentage | 9.80% | ||||||||
Approved decrease in fuel rates amount | $ 44 | ||||||||
Chattanooga Gas | Subsequent Event | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, requested rate increase (decrease), amount | $ 1 | ||||||||
Public utilities, requested return on equity, percentage | 9.80% | ||||||||
Virginia Natural Gas | Impact of Tax Reform Legislation | |||||||||
Loss Contingencies [Line Items] | |||||||||
Regulatory liabilities | $ 9 | ||||||||
Virginia Natural Gas | Subsequent Event | |||||||||
Loss Contingencies [Line Items] | |||||||||
Customer refund | $ 14 | ||||||||
Minimum | Florida City Gas | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, requested return on equity, percentage | 10.55% | ||||||||
Maximum | Florida City Gas | |||||||||
Loss Contingencies [Line Items] | |||||||||
Public utilities, requested return on equity, percentage | 10.95% |
Contingencies and Regulatory_10
Contingencies and Regulatory Matters - Nuclear Construction (Details) - GEORGIA POWER CO | Jan. 01, 2021 | Jan. 01, 2020 | Nov. 09, 2018USD ($) | Aug. 31, 2018USD ($) | Jan. 11, 2018USD ($) | Jan. 01, 2016 | Sep. 30, 2018USD ($)subcontractor | Jun. 30, 2018USD ($) | Sep. 30, 2018USD ($)subcontractorMW | Dec. 31, 2019USD ($) | Dec. 31, 2018USD ($) | Dec. 31, 2017USD ($)report | Dec. 31, 2009USD ($)utilityMW | Dec. 31, 2022USD ($) | Dec. 31, 2017USD ($) | Jun. 01, 2021 | Mar. 08, 2018appeal | Sep. 30, 2017USD ($) | Dec. 31, 2013 |
Loss Contingencies [Line Items] | |||||||||||||||||||
Number of construction units approved | utility | 2 | ||||||||||||||||||
Electric generating capacity in mega watts under consortium agreement | MW | 1,100 | ||||||||||||||||||
Additional construction capital costs | $ 3,300,000,000 | ||||||||||||||||||
Estimated in-service capital cost | $ 4,418,000,000 | ||||||||||||||||||
Financing costs collected, net of tax | $ 1,800,000,000 | ||||||||||||||||||
Amendment to estimated in-service capital cost | $ 5,680,000,000 | ||||||||||||||||||
Retail rate of return on common equity | 10.95% | ||||||||||||||||||
Eligible project costs to be reimbursed | 3,460,000,000 | ||||||||||||||||||
Scenario, Forecast | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Increase in NCCR tariff | $ 90,000,000 | ||||||||||||||||||
FFB Loan | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Long-term line of credit | $ 2,600,000,000 | 2,600,000,000 | |||||||||||||||||
Conditional borrowing commitment | $ 1,670,000,000 | ||||||||||||||||||
Plant Vogtle Units 3 And 4 | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Construction financing costs | 1,800,000,000 | ||||||||||||||||||
Increase in base project capital cost forecast | $ 700,000,000 | ||||||||||||||||||
Estimated project costs | 1,100,000,000 | ||||||||||||||||||
Increase in expected costs | $ 800,000,000 | ||||||||||||||||||
Base project capital cost forecast, monthly | 50,000,000 | ||||||||||||||||||
Monthly AFUDC | 12,000,000 | ||||||||||||||||||
Percentage of ownership interest required for voting for continuing construction | 90.00% | ||||||||||||||||||
Project capital cost forecast | $ 8,400,000,000 | 8,400,000,000 | |||||||||||||||||
Additional construction capital costs | $ 4,900,000,000 | ||||||||||||||||||
Construction costs, threshold | $ 2,100,000,000 | ||||||||||||||||||
Percentage of remaining share of construction costs to pay | 100.00% | ||||||||||||||||||
Percentage of cost savings | 60.70% | ||||||||||||||||||
Increase costs amount | $ 100,000 | ||||||||||||||||||
Percentage of approval required to change primary construction contractor | 90.00% | 90.00% | |||||||||||||||||
Percent disallowed for recovery | 6.00% | ||||||||||||||||||
Disallowed for recovery reporting period | 6 months | ||||||||||||||||||
Extension in project schedule | 1 year | ||||||||||||||||||
Percentage of approval required for material amendments | 67.00% | 67.00% | |||||||||||||||||
Voted in favor period | 30 days | ||||||||||||||||||
Ownership interests voted in favor | 50.00% | ||||||||||||||||||
Share of plants (mw) | MW | 206 | ||||||||||||||||||
Aggregate purchase price not to exceed | $ 300,000,000 | ||||||||||||||||||
Funding for project | 250,000,000 | ||||||||||||||||||
Cost settlement agreement revised forecast, net of payments | $ 7,300,000,000 | 7,300,000,000 | |||||||||||||||||
Public utilities, approved return on equity percentage | 10.00% | ||||||||||||||||||
Return on equity reduction, negative impact on earnings | $ 25,000,000 | ||||||||||||||||||
Number Of Appeals | appeal | 2 | ||||||||||||||||||
Number of VCM reports approved | report | 18 | ||||||||||||||||||
Guarantor obligations | $ 1,700,000,000 | 1,700,000,000 | |||||||||||||||||
Customer refund | $ 188,000,000 | ||||||||||||||||||
Requested capital construction costs | $ 578,000,000 | ||||||||||||||||||
Plant Vogtle Units 3 And 4 | Scenario, Forecast | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Construction financing costs | $ 3,200,000,000 | ||||||||||||||||||
Public utilities, approved return on equity percentage | 5.30% | 8.30% | |||||||||||||||||
Approved return on equity, monthly percentage decrease | 0.10% | ||||||||||||||||||
Return on equity reduction, negative impact on earnings | $ 100,000,000 | $ 680,000,000 | |||||||||||||||||
Plant Vogtle Units 3 And 4 | Vogtle Owners | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Period of notice required in the event letters of credit are not renewed | 30 days | ||||||||||||||||||
Percentage of cost savings | 39.30% | ||||||||||||||||||
Plant Vogtle Units 3 And 4 | Minimum | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Number of subcontractors | subcontractor | 60 | 60 | |||||||||||||||||
Category I | Plant Vogtle Units 3 And 4 | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Additional construction capital costs | $ 800,000,000 | ||||||||||||||||||
Category II | Plant Vogtle Units 3 And 4 | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Percentage of construction costs responsible to pay | 55.70% | ||||||||||||||||||
Category II | Plant Vogtle Units 3 And 4 | Vogtle Owners | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Percentage of construction costs responsible to pay | 44.30% | ||||||||||||||||||
Category II | Plant Vogtle Units 3 And 4 | Minimum | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Additional construction capital costs | $ 80,000,000 | ||||||||||||||||||
Construction costs, threshold | 800,000,000 | ||||||||||||||||||
Category II | Plant Vogtle Units 3 And 4 | Maximum | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Construction costs, threshold | $ 1,600,000,000 | ||||||||||||||||||
Category III | Plant Vogtle Units 3 And 4 | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Percentage of construction costs responsible to pay | 65.70% | ||||||||||||||||||
Category III | Plant Vogtle Units 3 And 4 | Vogtle Owners | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Percentage of construction costs responsible to pay | 34.30% | ||||||||||||||||||
Category III | Plant Vogtle Units 3 And 4 | Minimum | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Additional construction capital costs | $ 100,000,000 | ||||||||||||||||||
Construction costs, threshold | 1,600,000,000 | ||||||||||||||||||
Category III | Plant Vogtle Units 3 And 4 | Maximum | |||||||||||||||||||
Loss Contingencies [Line Items] | |||||||||||||||||||
Construction costs, threshold | $ 2,100,000,000 |
Contingencies and Regulatory_11
Contingencies and Regulatory Matters - Nuclear Construction Cost and Schedule (Details) - GEORGIA POWER CO - Plant Vogtle Units 3 And 4 $ in Millions | 9 Months Ended |
Sep. 30, 2018USD ($) | |
Loss Contingencies [Line Items] | |
Base project capital cost forecast | $ 8,000 |
Construction contingency estimate | 400 |
Project capital cost forecast | 8,400 |
Net investment as of June 30, 2018 | (4,300) |
Remaining estimate to complete | 4,100 |
Expected capitalized costs | 350 |
Guarantor obligations | 1,700 |
Customer refund | $ 188 |
Contingencies and Regulatory_12
Contingencies and Regulatory Matters - Kemper County Energy Facility (Details) - MISSISSIPPI POWER CO - USD ($) $ in Millions | Aug. 06, 2018 | Dec. 31, 2018 | Sep. 30, 2018 | Sep. 30, 2018 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2017 |
Loss Contingencies [Line Items] | |||||||
Accrued plant closure costs | $ 30 | $ 30 | $ 35 | ||||
Kemper County Energy Facility | |||||||
Loss Contingencies [Line Items] | |||||||
Public utilities, charges to income | 0 | 45 | |||||
Public utilities, charges to income, after tax | 34 | ||||||
Accrued plant closure costs | $ 20 | $ 20 | |||||
Reserve Margin Plan | Plant Watson, Unit 4 | |||||||
Loss Contingencies [Line Items] | |||||||
Accelerated retirement period | 2 years | ||||||
Reserve Margin Plan | Plant Watson, Unit 5 | |||||||
Loss Contingencies [Line Items] | |||||||
Accelerated retirement period | 7 years | ||||||
Reserve Margin Plan | Plant Greene County Units 1 and 2 | |||||||
Loss Contingencies [Line Items] | |||||||
Accelerated retirement period | 4 years | ||||||
Scenario, Forecast | Kemper County Energy Facility | |||||||
Loss Contingencies [Line Items] | |||||||
Production costs, period cost | $ 2 | $ 4 | $ 8 |
Contingencies and Regulatory_13
Contingencies and Regulatory Matters - Other Matters (Details) | 9 Months Ended | 12 Months Ended |
Sep. 30, 2018USD ($)cavern | Dec. 31, 2017USD ($) | |
Southern Company Holdings Subsidiary | ||
Loss Contingencies [Line Items] | ||
Lease receivable | $ 86,000,000 | |
Number of salt dome caverns | cavern | 2 | |
SOUTHERN Co GAS | ||
Loss Contingencies [Line Items] | ||
Impairment of long-lived assets | $ 0 | |
Natural Gas, Storage | ||
Loss Contingencies [Line Items] | ||
Property, plant and equipment, net book value | $ 110,000,000 | |
Natural Gas Storage - Salt Dome Caverns | ||
Loss Contingencies [Line Items] | ||
Percentage of total property, plant and equipment | 20.00% |
Revenue from Contracts with C_3
Revenue from Contracts with Customers - Disaggregate Revenue Sources (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | $ 6,159 | $ 18,158 | ||
Total operating revenues | 6,159 | $ 6,201 | 18,158 | $ 17,403 |
Other Income | 92 | 274 | ||
Retail electric revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Leases revenues | 17 | 54 | ||
Increase (decrease) in revenue from cost recovery mechanisms | (98) | 4 | ||
Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 2,148 | 5,266 | ||
Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1,527 | 4,084 | ||
Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 901 | 2,471 | ||
Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 29 | 92 | ||
Natural gas distribution revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 433 | 2,299 | ||
Alternative revenue programs | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 5 | (23) | ||
Total retail electric and gas distribution revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 5,043 | 14,189 | ||
Wholesale energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 516 | 1,444 | ||
Revenue from transactions accounted for as derivatives | 63 | 217 | ||
Lease income from PPA contracts | 130 | 318 | ||
Wholesale capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 177 | 479 | ||
Lease income from PPA contracts | 31 | 92 | ||
Other natural gas revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 54 | 530 | ||
Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 369 | 1,516 | ||
Total operating revenues | 199 | 168 | 1,007 | 494 |
SOUTHERN Co GAS | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 492 | 2,861 | ||
Total operating revenues | 492 | 565 | 2,861 | 2,841 |
SOUTHERN Co GAS | Natural gas distribution revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 438 | 2,276 | ||
SOUTHERN Co GAS | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 149 | 1,082 | ||
SOUTHERN Co GAS | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 45 | 313 | ||
SOUTHERN Co GAS | Transportation | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 203 | 708 | ||
SOUTHERN Co GAS | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 4 | 28 | ||
SOUTHERN Co GAS | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 32 | 168 | ||
SOUTHERN Co GAS | Alternative revenue programs | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 5 | (23) | ||
SOUTHERN Co GAS | Gas marketing Services | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 44 | 403 | ||
Other Income | 4 | |||
SOUTHERN Co GAS | Wholesale gas services | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | (10) | 121 | ||
SOUTHERN Co GAS | Gas midstream operations | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 20 | 60 | ||
SOUTHERN Co GAS | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 0 | 1 | ||
Total operating revenues | 0 | 33 | 55 | 95 |
ALABAMA POWER CO | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1,740 | 4,716 | ||
Total operating revenues | 1,740 | 1,740 | 4,716 | 4,606 |
Other Income | 27 | 79 | ||
ALABAMA POWER CO | Retail electric revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1,584 | 4,208 | ||
Increase (decrease) in revenue from cost recovery mechanisms | (12) | 113 | ||
ALABAMA POWER CO | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 721 | 1,848 | ||
ALABAMA POWER CO | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 464 | 1,238 | ||
ALABAMA POWER CO | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 392 | 1,103 | ||
ALABAMA POWER CO | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 7 | 19 | ||
ALABAMA POWER CO | Wholesale energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 62 | 234 | ||
Revenue from transactions accounted for as derivatives | 6 | 14 | ||
ALABAMA POWER CO | Wholesale capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 26 | 75 | ||
ALABAMA POWER CO | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 68 | 199 | ||
Total operating revenues | 68 | 50 | 199 | 158 |
GEORGIA POWER CO | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 2,593 | 6,601 | ||
Total operating revenues | 2,593 | 2,546 | 6,601 | 6,426 |
Other Income | 28 | 80 | ||
GEORGIA POWER CO | Retail electric revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 2,425 | 6,112 | ||
Leases revenues | 17 | 54 | ||
Increase (decrease) in revenue from cost recovery mechanisms | (47) | (35) | ||
GEORGIA POWER CO | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1,142 | 2,671 | ||
GEORGIA POWER CO | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 877 | 2,343 | ||
GEORGIA POWER CO | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 385 | 1,036 | ||
GEORGIA POWER CO | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 21 | 62 | ||
GEORGIA POWER CO | Wholesale energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 33 | 99 | ||
Revenue from transactions accounted for as derivatives | 8 | 21 | ||
GEORGIA POWER CO | Wholesale capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 14 | 41 | ||
GEORGIA POWER CO | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 121 | 349 | ||
Leases revenues | 34 | 100 | ||
Total operating revenues | 121 | 93 | 349 | 284 |
GULF POWER CO | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 414 | 1,106 | ||
Total operating revenues | 414 | 437 | 1,106 | 1,144 |
Other Income | 2 | 5 | ||
GULF POWER CO | Retail electric revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 341 | 932 | ||
Increase (decrease) in revenue from cost recovery mechanisms | (36) | (63) | ||
GULF POWER CO | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 200 | 537 | ||
GULF POWER CO | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 103 | 291 | ||
GULF POWER CO | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 37 | 100 | ||
GULF POWER CO | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1 | 4 | ||
GULF POWER CO | Wholesale energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 48 | 104 | ||
GULF POWER CO | Wholesale capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 7 | 20 | ||
GULF POWER CO | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 18 | 50 | ||
Total operating revenues | 18 | 20 | 50 | 53 |
MISSISSIPPI POWER CO | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 358 | 956 | ||
Total operating revenues | 358 | 341 | 956 | 915 |
MISSISSIPPI POWER CO | Retail electric revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 254 | 660 | ||
Increase (decrease) in revenue from cost recovery mechanisms | (3) | (11) | ||
MISSISSIPPI POWER CO | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 85 | 209 | ||
MISSISSIPPI POWER CO | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 82 | 212 | ||
MISSISSIPPI POWER CO | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 86 | 233 | ||
MISSISSIPPI POWER CO | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1 | 6 | ||
MISSISSIPPI POWER CO | Wholesale energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 92 | 259 | ||
MISSISSIPPI POWER CO | Wholesale capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 1 | 6 | ||
MISSISSIPPI POWER CO | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 11 | 31 | ||
Total operating revenues | 11 | 5 | 31 | 14 |
SOUTHERN POWER CO | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 635 | 1,699 | ||
Total operating revenues | 635 | 618 | 1,699 | 1,597 |
SOUTHERN POWER CO | PPA capacity revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 168 | 450 | ||
Lease income from PPA contracts | 47 | 141 | ||
SOUTHERN POWER CO | PPA energy revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 336 | 892 | ||
Revenue from transactions accounted for as derivatives | 47 | 176 | ||
Lease income from PPA contracts | 139 | 342 | ||
SOUTHERN POWER CO | Non-PPA revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 126 | 347 | ||
SOUTHERN POWER CO | Other revenues | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 5 | 10 | ||
Total operating revenues | 5 | 3 | 10 | 9 |
Operating Segments | SOUTHERN Co GAS | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | 497 | 607 | 2,902 | 3,000 |
Wholesale gas services | Operating Segments | SOUTHERN Co GAS | ||||
Disaggregation of Revenue [Line Items] | ||||
Total operating revenues | (8) | (24) | 142 | 95 |
Wholesale gas services | Third Party Gross Revenues | Operating Segments | SOUTHERN Co GAS | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from transactions accounted for as derivatives | 900 | 2,700 | ||
Total operating revenues | $ 1,573 | $ 1,411 | $ 4,847 | $ 4,781 |
Revenue from Contracts with C_4
Revenue from Contracts with Customers - Contract Balances (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2018USD ($) | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | $ 2,778 |
Contract Assets | 99 |
Contract Liabilities | 34 |
Unregulated Distributed Generation | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Contract Assets | 27 |
Contract Liabilities | 17 |
ALABAMA POWER CO | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | 649 |
Contract Assets | 1 |
Contract Liabilities | 14 |
GEORGIA POWER CO | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | 924 |
Contract Assets | 70 |
Contract Liabilities | $ 3 |
Performance obligation, expected timing of satisfaction | Georgia Power had contract assets primarily related to fixed retail customer bill programs where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over the one-year contract term. |
GULF POWER CO | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | $ 186 |
Contract Assets | 0 |
Contract Liabilities | 0 |
MISSISSIPPI POWER CO | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | 96 |
Contract Assets | 0 |
Contract Liabilities | 0 |
SOUTHERN POWER CO | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | 142 |
Contract Assets | 0 |
Contract Liabilities | 17 |
SOUTHERN Co GAS | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Receivables | 523 |
Contract Assets | 0 |
Contract Liabilities | $ 1 |
Revenue from Contracts with C_5
Revenue from Contracts with Customers - Performance Obligations (Details) $ in Millions | Sep. 30, 2018USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 168 |
Performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 406 |
Performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 322 |
Performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 322 |
Performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 310 |
Performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 2,112 |
Performance obligation, expected timing of satisfaction | |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 6 |
Performance obligation, expected timing of satisfaction | 1 year |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 22 |
Performance obligation, expected timing of satisfaction | 1 year |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 22 |
Performance obligation, expected timing of satisfaction | 1 year |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 26 |
Performance obligation, expected timing of satisfaction | 1 year |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 23 |
Performance obligation, expected timing of satisfaction | 1 year |
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 161 |
Performance obligation, expected timing of satisfaction | |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 10 |
Performance obligation, expected timing of satisfaction | 1 year |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 41 |
Performance obligation, expected timing of satisfaction | 1 year |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 38 |
Performance obligation, expected timing of satisfaction | 1 year |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 40 |
Performance obligation, expected timing of satisfaction | 1 year |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 30 |
Performance obligation, expected timing of satisfaction | 1 year |
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 113 |
Performance obligation, expected timing of satisfaction | |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 5 |
Performance obligation, expected timing of satisfaction | 1 year |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 22 |
Performance obligation, expected timing of satisfaction | 1 year |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | 1 year |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | 1 year |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | 1 year |
GULF POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 1 |
Performance obligation, expected timing of satisfaction | 1 year |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 3 |
Performance obligation, expected timing of satisfaction | 1 year |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 3 |
Performance obligation, expected timing of satisfaction | 1 year |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 1 |
Performance obligation, expected timing of satisfaction | 1 year |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | 1 year |
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 0 |
Performance obligation, expected timing of satisfaction | |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 75 |
Performance obligation, expected timing of satisfaction | 1 year |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 310 |
Performance obligation, expected timing of satisfaction | 1 year |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 283 |
Performance obligation, expected timing of satisfaction | 1 year |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 277 |
Performance obligation, expected timing of satisfaction | 1 year |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 276 |
Performance obligation, expected timing of satisfaction | 1 year |
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, remaining performance obligation | $ 2,005 |
Performance obligation, expected timing of satisfaction |
Fair Value Measurements - Asset
Fair Value Measurements - Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Liabilities: | ||
Collateral already posted, aggregate fair value | $ 189 | |
Net Asset Value as a Practical Expedient (NAV) | ||
Assets: | ||
Net Asset Value as a Practical Expedient (NAV) | 37 | |
Net Asset Value as a Practical Expedient (NAV) | Nuclear Decommissioning Trusts | ||
Assets: | ||
Net Asset Value as a Practical Expedient (NAV) | 37 | |
ALABAMA POWER CO | ||
Assets: | ||
Energy-related derivatives | 7 | $ 4 |
Liabilities: | ||
Energy-related derivatives | 10 | 10 |
ALABAMA POWER CO | Net Asset Value as a Practical Expedient (NAV) | ||
Assets: | ||
Net Asset Value as a Practical Expedient (NAV) | 37 | |
ALABAMA POWER CO | Net Asset Value as a Practical Expedient (NAV) | Nuclear Decommissioning Trusts | ||
Assets: | ||
Net Asset Value as a Practical Expedient (NAV) | 37 | |
GEORGIA POWER CO | ||
Assets: | ||
Energy-related derivatives | 7 | 6 |
Nuclear decommissioning trusts | 37 | |
Liabilities: | ||
Energy-related derivatives | 28 | 24 |
GEORGIA POWER CO | Net Asset Value as a Practical Expedient (NAV) | ||
Assets: | ||
Net Asset Value as a Practical Expedient (NAV) | 0 | |
GULF POWER CO | ||
Assets: | ||
Energy-related derivatives | 0 | 0 |
Liabilities: | ||
Energy-related derivatives | 8 | 21 |
MISSISSIPPI POWER CO | ||
Assets: | ||
Energy-related derivatives | 3 | 3 |
Liabilities: | ||
Energy-related derivatives | 9 | 9 |
SOUTHERN POWER CO | ||
Assets: | ||
Energy-related derivatives | 125 | 132 |
Liabilities: | ||
Energy-related derivatives | 30 | 36 |
SOUTHERN Co GAS | ||
Assets: | ||
Energy-related derivatives | 400 | 554 |
Liabilities: | ||
Energy-related derivatives | 516 | 660 |
Collateral already posted, aggregate fair value | 189 | $ 193 |
Fair Value, Measurements, Recurring | ||
Assets: | ||
Energy-related derivatives | 421 | |
Foreign currency derivatives | 122 | |
Nuclear decommissioning trusts | 1,872 | |
Cash equivalents | 1,309 | |
Total | 3,778 | |
Liabilities: | ||
Energy-related derivatives | 575 | |
Interest rate derivatives | 72 | |
Foreign currency derivatives | 23 | |
Contingent consideration | 22 | |
Total | 692 | |
Fair Value, Measurements, Recurring | Weather Derivative | ||
Assets: | ||
Energy-related derivatives | 5 | |
Fair Value, Measurements, Recurring | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 11 | |
Fair Value, Measurements, Recurring | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 6 | |
Fair Value, Measurements, Recurring | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 13 | |
Fair Value, Measurements, Recurring | Cash equivalents | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 15 | |
Fair Value, Measurements, Recurring | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 9 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 271 | |
Foreign currency derivatives | 0 | |
Nuclear decommissioning trusts | 828 | |
Cash equivalents | 1,309 | |
Total | 2,432 | |
Liabilities: | ||
Energy-related derivatives | 416 | |
Interest rate derivatives | 0 | |
Foreign currency derivatives | 0 | |
Contingent consideration | 0 | |
Total | 416 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | Cash equivalents | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 15 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 9 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 150 | |
Foreign currency derivatives | 122 | |
Nuclear decommissioning trusts | 1,007 | |
Cash equivalents | 0 | |
Total | 1,309 | |
Liabilities: | ||
Energy-related derivatives | 159 | |
Interest rate derivatives | 72 | |
Foreign currency derivatives | 23 | |
Contingent consideration | 0 | |
Total | 254 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 11 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 6 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 13 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Cash equivalents | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Foreign currency derivatives | 0 | |
Nuclear decommissioning trusts | 0 | |
Cash equivalents | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Interest rate derivatives | 0 | |
Foreign currency derivatives | 0 | |
Contingent consideration | 22 | |
Total | 22 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Cash equivalents | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | ||
Assets: | ||
Energy-related derivatives | 7 | |
Cash equivalents | 513 | |
Total | 1,458 | |
Liabilities: | ||
Energy-related derivatives | 10 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 558 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 116 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 18 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 180 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 22 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | ||
Assets: | ||
Nuclear decommissioning trusts | 37 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | ||
Assets: | ||
Nuclear decommissioning trusts | 7 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 513 | |
Total | 1,075 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 469 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 60 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 26 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Private equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Other | ||
Assets: | ||
Nuclear decommissioning trusts | 7 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 7 | |
Cash equivalents | 0 | |
Total | 346 | |
Liabilities: | ||
Energy-related derivatives | 10 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 89 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 56 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 18 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 154 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 22 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Private equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2) | Other | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Private equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3) | Other | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | ||
Assets: | ||
Energy-related derivatives | 8 | |
Cash equivalents | 350 | |
Total | 1,291 | |
Liabilities: | ||
Energy-related derivatives | 22 | |
Interest rate derivatives | 6 | |
Total | 28 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 251 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 134 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 236 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 82 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 163 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 42 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 25 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 350 | |
Total | 616 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Interest rate derivatives | 0 | |
Total | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 250 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Municipal bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 16 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 8 | |
Cash equivalents | 0 | |
Total | 675 | |
Liabilities: | ||
Energy-related derivatives | 22 | |
Interest rate derivatives | 6 | |
Total | 28 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 1 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 134 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 236 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Municipal bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 82 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 163 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 42 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 9 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Interest rate derivatives | 0 | |
Total | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Domestic equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Foreign equity | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | U.S. Treasury and government agency securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Municipal bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Corporate bonds | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Mortgage and asset backed securities | ||
Assets: | ||
Nuclear decommissioning trusts | 0 | |
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | GULF POWER CO | ||
Assets: | ||
Cash equivalents | 27 | |
Liabilities: | ||
Energy-related derivatives | 8 | |
Fair Value, Measurements, Recurring | GULF POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Cash equivalents | 27 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | GULF POWER CO | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Cash equivalents | 0 | |
Liabilities: | ||
Energy-related derivatives | 8 | |
Fair Value, Measurements, Recurring | GULF POWER CO | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Cash equivalents | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | ||
Assets: | ||
Energy-related derivatives | 3 | |
Cash equivalents | 346 | |
Total | 349 | |
Liabilities: | ||
Energy-related derivatives | 9 | |
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 346 | |
Total | 346 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 3 | |
Cash equivalents | 0 | |
Total | 3 | |
Liabilities: | ||
Energy-related derivatives | 9 | |
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | ||
Assets: | ||
Energy-related derivatives | 3 | |
Foreign currency derivatives | 122 | |
Total | 125 | |
Liabilities: | ||
Energy-related derivatives | 7 | |
Foreign currency derivatives | 23 | |
Contingent consideration | 22 | |
Total | 52 | |
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Foreign currency derivatives | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Foreign currency derivatives | 0 | |
Contingent consideration | 0 | |
Total | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 3 | |
Foreign currency derivatives | 122 | |
Total | 125 | |
Liabilities: | ||
Energy-related derivatives | 7 | |
Foreign currency derivatives | 23 | |
Contingent consideration | 0 | |
Total | 30 | |
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Foreign currency derivatives | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Foreign currency derivatives | 0 | |
Contingent consideration | 22 | |
Total | 22 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | ||
Assets: | ||
Energy-related derivatives | 400 | |
Cash equivalents | 26 | |
Total | 460 | |
Liabilities: | ||
Energy-related derivatives | 517 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 11 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 6 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 13 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 4 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Assets: | ||
Energy-related derivatives | 271 | |
Cash equivalents | 26 | |
Total | 301 | |
Liabilities: | ||
Energy-related derivatives | 416 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 4 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2) | ||
Assets: | ||
Energy-related derivatives | 129 | |
Cash equivalents | 0 | |
Total | 159 | |
Liabilities: | ||
Energy-related derivatives | 101 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 11 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 6 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 13 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | ||
Assets: | ||
Energy-related derivatives | 0 | |
Cash equivalents | 0 | |
Total | 0 | |
Liabilities: | ||
Energy-related derivatives | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Domestic equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Foreign equity | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Pooled funds – fixed income | ||
Assets: | ||
Non-qualified deferred compensation trusts: | 0 | |
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Other | ||
Assets: | ||
Non-qualified deferred compensation trusts: | $ 0 |
Fair Value Measurements - Sched
Fair Value Measurements - Schedule of Increase (Decrease) In Fair Value Of Funds (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Fair Value, Option, Quantitative Disclosures [Line Items] | ||||
Increase (decrease) in fair value of funds | $ 58 | $ 50 | $ 68 | $ 168 |
ALABAMA POWER CO | ||||
Fair Value, Option, Quantitative Disclosures [Line Items] | ||||
Increase (decrease) in fair value of funds | 39 | 25 | 49 | 87 |
GEORGIA POWER CO | ||||
Fair Value, Option, Quantitative Disclosures [Line Items] | ||||
Increase (decrease) in fair value of funds | $ 19 | $ 25 | $ 19 | $ 81 |
Fair Value Measurements - Fair
Fair Value Measurements - Fair Value Measurements Of Investments Calculated At Net Asset Value Per Share (Details) $ in Millions | Sep. 30, 2018USD ($) |
Private equity | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Unfunded Commitments | $ 47 |
ALABAMA POWER CO | Private equity | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Unfunded Commitments | 47 |
Net Asset Value as a Practical Expedient (NAV) | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Fair Value | 37 |
Net Asset Value as a Practical Expedient (NAV) | Private equity | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Fair Value | 37 |
Net Asset Value as a Practical Expedient (NAV) | ALABAMA POWER CO | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Fair Value | 37 |
Net Asset Value as a Practical Expedient (NAV) | ALABAMA POWER CO | Private equity | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Fair Value | $ 37 |
Fair Value Measurements - Narra
Fair Value Measurements - Narrative (Details) | 9 Months Ended |
Sep. 30, 2018 | |
Private equity | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items] | |
Liquidations term | 10 years |
Fair Value Measurements - Finan
Fair Value Measurements - Financial Instruments for which Carrying Amount did not Equal Fair Value (Details) $ in Millions | Sep. 30, 2018USD ($) |
Southern Company | |
Long-term debt, including securities due within one year: | |
Carrying Amount | $ 45,524 |
Fair Value | 45,500 |
ALABAMA POWER CO | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 8,120 |
Fair Value | 8,321 |
GEORGIA POWER CO | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 10,227 |
Fair Value | 10,159 |
GULF POWER CO | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 1,285 |
Fair Value | 1,290 |
MISSISSIPPI POWER CO | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 1,736 |
Fair Value | 1,702 |
SOUTHERN POWER CO | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 5,029 |
Fair Value | 5,058 |
SOUTHERN Co GAS | |
Long-term debt, including securities due within one year: | |
Carrying Amount | 5,908 |
Fair Value | $ 5,935 |
Stockholders' Equity - Earnings
Stockholders' Equity - Earnings per Share (Details) - shares shares in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Equity [Abstract] | ||||
As reported shares (in shares) | 1,023 | 1,003 | 1,016 | 998 |
Effect of stock-based compensation (in shares) | 6 | 7 | 5 | 7 |
Diluted shares (in shares) | 1,029 | 1,010 | 1,021 | 1,005 |
Stockholders' Equity - Changes
Stockholders' Equity - Changes in Stockholders' Equity (Details) - USD ($) shares in Thousands, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Changes in Stockholders' Equity | ||||
Beginning balance, treasury shares (in shares) | (900) | |||
Beginning balance | $ 25,528 | $ 26,612 | ||
Consolidated net income attributable to Southern Company | $ 1,164 | $ 1,069 | 1,948 | 347 |
Other comprehensive income (loss) | 52 | (2) | ||
Stock issued | 878 | 613 | ||
Stock-based compensation | 74 | 97 | ||
Cash dividends on common stock | (1,805) | (1,716) | ||
Preference stock redemption | (150) | |||
Contributions from noncontrolling interests | 154 | 77 | ||
Distributions to noncontrolling interests | (87) | (87) | ||
Net income attributable to noncontrolling interests | 71 | 45 | ||
Sale of noncontrolling interests | 1,280 | |||
Reclassification from redeemable noncontrolling interests | 114 | |||
Other | $ (28) | (11) | ||
Ending balance, treasury shares (in shares) | (1,000) | (1,000) | ||
Ending balance | $ 28,065 | $ 25,939 | $ 28,065 | $ 25,939 |
Number of Common Shares Issued | ||||
Changes in Stockholders' Equity | ||||
Beginning balance (in shares) | 1,008,532 | 991,213 | ||
Stock issued (in shares) | 21,342 | 13,308 | ||
Other (in shares) | 0 | |||
Ending balance (in shares) | 1,029,874 | 1,004,521 | 1,029,874 | 1,004,521 |
Number of Common Shares Treasury Issued | ||||
Changes in Stockholders' Equity | ||||
Beginning balance, treasury shares (in shares) | (929) | (819) | ||
Other (in shares) | (57) | (75) | ||
Ending balance, treasury shares (in shares) | (986) | (894) | (986) | (894) |
Common Stockholders' Equity | ||||
Changes in Stockholders' Equity | ||||
Beginning balance | $ 24,167 | $ 24,758 | ||
Consolidated net income attributable to Southern Company | 1,948 | 347 | ||
Other comprehensive income (loss) | 52 | (2) | ||
Stock issued | 878 | 613 | ||
Stock-based compensation | 74 | 97 | ||
Cash dividends on common stock | (1,805) | (1,716) | ||
Sale of noncontrolling interests | (410) | |||
Other | (27) | (15) | ||
Ending balance | $ 24,877 | $ 24,082 | 24,877 | 24,082 |
Preferred and Preference Stock of Subsidiaries | ||||
Changes in Stockholders' Equity | ||||
Beginning balance | 0 | 609 | ||
Preference stock redemption | (150) | |||
Other | 3 | |||
Ending balance | 0 | 462 | 0 | 462 |
Noncontrolling Interests | ||||
Changes in Stockholders' Equity | ||||
Beginning balance | 1,361 | 1,245 | ||
Contributions from noncontrolling interests | 154 | 77 | ||
Distributions to noncontrolling interests | (87) | (87) | ||
Net income attributable to noncontrolling interests | 71 | 45 | ||
Sale of noncontrolling interests | 1,690 | |||
Reclassification from redeemable noncontrolling interests | 114 | |||
Other | (1) | 1 | ||
Ending balance | $ 3,188 | $ 1,395 | $ 3,188 | $ 1,395 |
Financing - Narrative (Details)
Financing - Narrative (Details) | 1 Months Ended | 3 Months Ended | 9 Months Ended | ||||||||||
Nov. 06, 2018USD ($)shares | Aug. 31, 2018USD ($) | Jun. 30, 2018USD ($)agreement | May 31, 2018USD ($)agreement | Apr. 30, 2018USD ($) | Mar. 31, 2018USD ($) | Sep. 30, 2018USD ($) | Jun. 30, 2018USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Jul. 31, 2018USD ($) | Jan. 31, 2018USD ($) | Jan. 04, 2018USD ($) | |
Debt Instrument [Line Items] | |||||||||||||
Variable rate pollution control revenue bonds outstanding | $ 1,500,000,000 | $ 1,500,000,000 | |||||||||||
Maximum borrowing capacity | 8,143,000,000 | 8,143,000,000 | |||||||||||
Repayments of short-term debt | 1,800,000,000 | $ 409,000,000 | |||||||||||
Stock redeemed during period, par value | 150,000,000 | ||||||||||||
Floating rate Promissory Note Due July 2018 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 100,000,000 | ||||||||||||
Southern Company | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Maximum borrowing capacity | 2,000,000,000 | 2,000,000,000 | |||||||||||
Southern Company | Floating Rate Bank Term Loan Agreement 1 | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 900,000,000 | ||||||||||||
Southern Company | Uncommitted Bank Credit Arrangement | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 250,000,000 | ||||||||||||
Debt instrument, payable by demand from bank, term | 30 days | ||||||||||||
Repayments of short-term debt | $ 250,000,000 | ||||||||||||
Southern Company | Floating Rate Bank Term Loan Agreement 6 | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 1,500,000,000 | ||||||||||||
Southern Company | Notes Payable to Banks | Floating Rate Bank Term Loan Agreement 1 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Number of loan agreements | agreement | 2 | ||||||||||||
Southern Company | Notes Payable to Banks | Floating Rate Bank Term Loan Agreement 4 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 100,000,000 | $ 100,000,000 | |||||||||||
Southern Company | Notes Payable to Banks | Floating Rate Bank Term Loan Agreement 5 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 100,000,000 | 100,000,000 | |||||||||||
Southern Company | Senior Notes | Series 2018A Floating Rate Senior Notes Due February 14, 2020 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 750,000,000 | ||||||||||||
ALABAMA POWER CO | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Variable rate pollution control revenue bonds outstanding | 854,000,000 | 854,000,000 | |||||||||||
Fixed rate pollution control revenue bonds outstanding | 120,000,000 | 120,000,000 | |||||||||||
Maximum borrowing capacity | 1,333,000,000 | 1,333,000,000 | |||||||||||
ALABAMA POWER CO | Senior Notes | Series 2018A Floating Rate Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 500,000,000 | $ 500,000,000 | |||||||||||
Debt stated interest rate | 4.30% | 4.30% | |||||||||||
ALABAMA POWER CO | Senior Notes | Series 2008B 5.40% Senior Notes due June 1, 2018 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt stated interest rate | 5.40% | ||||||||||||
Repurchased face amount | $ 250,000,000 | ||||||||||||
ALABAMA POWER CO | Subsequent Event | Pollution Control Revenue Bonds | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt instrument, repurchase amount | $ 120,000,000 | ||||||||||||
GEORGIA POWER CO | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Variable rate pollution control revenue bonds outstanding | 550,000,000 | 550,000,000 | |||||||||||
Fixed rate pollution control revenue bonds outstanding | 345,000,000 | 345,000,000 | |||||||||||
Maximum borrowing capacity | 1,750,000,000 | $ 1,750,000,000 | |||||||||||
Amortization period for line of credit facility | 5 years | ||||||||||||
Percent of eligible project costs to be reimbursed | 70.00% | ||||||||||||
Repayments of short-term debt | $ 150,000,000 | 300,000,000 | |||||||||||
GEORGIA POWER CO | Loan Guarantee Agreement | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Conditional borrowing commitment | 1,670,000,000 | ||||||||||||
GEORGIA POWER CO | Notes Payable to Banks | Floating Rate Bank Term Loan Agreement 2 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 150,000,000 | ||||||||||||
GEORGIA POWER CO | Notes Payable to Banks | Floating Rate Bank Term Loan Agreement 3 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 100,000,000 | ||||||||||||
GEORGIA POWER CO | Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Repayments of debt | $ 902,000,000 | ||||||||||||
GEORGIA POWER CO | Senior Notes | Series 2007A 5.65% Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt instrument, repurchase amount | 89,000,000 | ||||||||||||
Debt face amount | $ 250,000,000 | ||||||||||||
Debt stated interest rate | 5.65% | ||||||||||||
GEORGIA POWER CO | Senior Notes | Series 2009A 5.95% Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt instrument, repurchase amount | $ 326,000,000 | ||||||||||||
Debt face amount | $ 500,000,000 | ||||||||||||
Debt stated interest rate | 5.95% | ||||||||||||
GEORGIA POWER CO | Senior Notes | Series 2010B 5.40% Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt instrument, repurchase amount | $ 335,000,000 | ||||||||||||
Debt face amount | $ 600,000,000 | ||||||||||||
Debt stated interest rate | 5.40% | ||||||||||||
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fifth Series 1995 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 104,600,000 | 104,600,000 | |||||||||||
GEORGIA POWER CO | Municipal bonds | Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 1997 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 173,000,000 | 173,000,000 | |||||||||||
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fifth Series 1994 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 55,000,000 | 55,000,000 | |||||||||||
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 65,000,000 | 65,000,000 | |||||||||||
GEORGIA POWER CO | Municipal bonds | Development Authority Of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 71,735,000 | 71,735,000 | |||||||||||
GEORGIA POWER CO | FFB Loan | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Conditional borrowing commitment | 1,670,000,000 | ||||||||||||
Maximum borrowing capacity | 2,600,000,000 | 2,600,000,000 | |||||||||||
GULF POWER CO | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Variable rate pollution control revenue bonds outstanding | 82,000,000 | 82,000,000 | |||||||||||
Fixed rate pollution control revenue bonds outstanding | 58,000,000 | 58,000,000 | |||||||||||
Maximum borrowing capacity | 280,000,000 | 280,000,000 | |||||||||||
MISSISSIPPI POWER CO | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Variable rate pollution control revenue bonds outstanding | 40,000,000 | 40,000,000 | |||||||||||
Fixed rate pollution control revenue bonds outstanding | 50,000,000 | 50,000,000 | |||||||||||
Maximum borrowing capacity | 100,000,000 | 100,000,000 | |||||||||||
Repayments of short-term debt | 300,000,000 | $ 109,000,000 | |||||||||||
MISSISSIPPI POWER CO | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 300,000,000 | ||||||||||||
MISSISSIPPI POWER CO | Senior Notes | Series 2018A Floating Rate Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | 300,000,000 | ||||||||||||
MISSISSIPPI POWER CO | Senior Notes | Series 2018B 3.95% Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 300,000,000 | ||||||||||||
Debt stated interest rate | 3.95% | ||||||||||||
MISSISSIPPI POWER CO | Municipal bonds | Pollution Control Revenue Bonds | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt instrument, repurchase amount | $ 43,000,000 | ||||||||||||
MISSISSIPPI POWER CO | Promissory Notes | Promissory Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Repayments of debt | 100,000,000 | $ 200,000,000 | |||||||||||
MISSISSIPPI POWER CO | Unsecured Debt | Unsecured Term Loan | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Repayments of debt | $ 900,000,000 | ||||||||||||
MISSISSIPPI POWER CO | Subsequent Event | Senior Notes | Series G 5.40% Senior Notes Due July 1, 2035 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt stated interest rate | 5.40% | ||||||||||||
Aggregate principal amount outstanding | $ 30,000,000 | ||||||||||||
MISSISSIPPI POWER CO | Subsequent Event | Senior Notes | Series 2009A 5.55% Senior Notes Due March 1, 2019 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt stated interest rate | 5.55% | ||||||||||||
Aggregate principal amount outstanding | $ 125,000,000 | ||||||||||||
MISSISSIPPI POWER CO | 4.40% Series Preferred Stock | Subsequent Event | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Stock redeemed during period (in shares) | shares | 8,867 | ||||||||||||
Stock redeemed during period, par value | $ 886,700 | ||||||||||||
Preferred stock, dividend rate | 4.40% | ||||||||||||
MISSISSIPPI POWER CO | 4.60% Series Preferred Stock | Subsequent Event | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Stock redeemed during period (in shares) | shares | 8,643 | ||||||||||||
Stock redeemed during period, par value | $ 864,300 | ||||||||||||
Preferred stock, dividend rate | 4.60% | ||||||||||||
MISSISSIPPI POWER CO | 4.72% Series Preferred Stock | Subsequent Event | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Stock redeemed during period (in shares) | shares | 16,700 | ||||||||||||
Stock redeemed during period, par value | $ 1,670,000 | ||||||||||||
Preferred stock, dividend rate | 4.72% | ||||||||||||
MISSISSIPPI POWER CO | Depository Shares | Subsequent Event | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Stock redeemed during period (in shares) | shares | 1,200,000 | ||||||||||||
Stock redeemed during period, par value | $ 30,000,000 | ||||||||||||
Interest in shares | 25.00% | ||||||||||||
MISSISSIPPI POWER CO | 5.25% Series Preferred Stock | Subsequent Event | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Preferred stock, dividend rate | 5.25% | ||||||||||||
Traditional Electric Operating Companies | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Fixed rate pollution control revenue bonds outstanding | 573,000,000 | 573,000,000 | |||||||||||
SOUTHERN POWER CO | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Maximum borrowing capacity | 750,000,000 | 750,000,000 | |||||||||||
Repayments of debt | $ 770,000,000 | ||||||||||||
Proceeds from third-party tax equity | 148,000,000 | ||||||||||||
SOUTHERN POWER CO | Floating Rate Bank Term Loan Agreement 1 | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 100,000,000 | ||||||||||||
Number of loan agreements | agreement | 2 | ||||||||||||
Repurchased face amount | $ 420,000,000 | $ 420,000,000 | |||||||||||
SOUTHERN POWER CO | Senior Notes | Series 2015A 1.50% Senior Notes | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt stated interest rate | 1.50% | 1.50% | |||||||||||
Repurchased face amount | $ 350,000,000 | $ 350,000,000 | |||||||||||
SOUTHERN Co GAS | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Maximum borrowing capacity | 1,900,000,000 | 1,900,000,000 | |||||||||||
SOUTHERN Co GAS | Uncommitted Bank Credit Arrangement | Notes Payable to Banks | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 95,000,000 | ||||||||||||
Debt instrument, payable by demand from bank, term | 30 days | ||||||||||||
SOUTHERN Co GAS | Senior Notes | Series 2017A | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 200,000,000 | $ 200,000,000 | |||||||||||
Nicor Gas | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Maximum borrowing capacity | $ 500,000,000 | $ 500,000,000 | |||||||||||
Nicor Gas | First Mortgage Bonds | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 300,000,000 | ||||||||||||
Nicor Gas | First Mortgage Bonds | First Mortgage Bonds Issued August 2018 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 100,000,000 | ||||||||||||
Nicor Gas | Subsequent Event | First Mortgage Bonds | First Mortgage Bonds Issued November 2018 | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt face amount | $ 200,000,000 |
Financing - Schedule of Credit
Financing - Schedule of Credit Arrangements (Details) | Sep. 30, 2018USD ($) |
Line of Credit Facility [Line Items] | |
Expires, 2018 | $ 20,000,000 |
Expires, 2019 | 188,000,000 |
Expires, 2020 | 735,000,000 |
Expires, 2022 | 7,200,000,000 |
Total | 8,143,000,000 |
Unused | 8,101,000,000 |
Executable Term Loans, One Year | 45,000,000 |
Expires Within One Year, Term Out | 45,000,000 |
Expires Within One Year, No Term Out | 63,000,000 |
Southern Company | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 0 |
Expires, 2020 | 0 |
Expires, 2022 | 2,000,000,000 |
Total | 2,000,000,000 |
Unused | 1,999,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 0 |
ALABAMA POWER CO | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 33,000,000 |
Expires, 2020 | 500,000,000 |
Expires, 2022 | 800,000,000 |
Total | 1,333,000,000 |
Unused | 1,333,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 33,000,000 |
GEORGIA POWER CO | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 0 |
Expires, 2020 | 0 |
Expires, 2022 | 1,750,000,000 |
Total | 1,750,000,000 |
Unused | 1,736,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 0 |
GULF POWER CO | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 20,000,000 |
Expires, 2019 | 25,000,000 |
Expires, 2020 | 235,000,000 |
Expires, 2022 | 0 |
Total | 280,000,000 |
Unused | 280,000,000 |
Executable Term Loans, One Year | 45,000,000 |
Expires Within One Year, Term Out | 45,000,000 |
Expires Within One Year, No Term Out | 0 |
MISSISSIPPI POWER CO | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 100,000,000 |
Expires, 2020 | 0 |
Expires, 2022 | 0 |
Total | 100,000,000 |
Unused | 100,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 0 |
SOUTHERN POWER CO | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 0 |
Expires, 2020 | 0 |
Expires, 2022 | 750,000,000 |
Total | 750,000,000 |
Unused | 728,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 0 |
SOUTHERN POWER CO | Standby Letters of Credit | |
Line of Credit Facility [Line Items] | |
Total | 120,000,000 |
Unused | 22,000,000 |
SOUTHERN Co GAS | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 0 |
Expires, 2020 | 0 |
Expires, 2022 | 1,900,000,000 |
Total | 1,900,000,000 |
Unused | 1,895,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 0 |
Other | |
Line of Credit Facility [Line Items] | |
Expires, 2018 | 0 |
Expires, 2019 | 30,000,000 |
Expires, 2020 | 0 |
Expires, 2022 | 0 |
Total | 30,000,000 |
Unused | 30,000,000 |
Executable Term Loans, One Year | 0 |
Expires Within One Year, Term Out | 0 |
Expires Within One Year, No Term Out | 30,000,000 |
Southern Company Gas Capital | |
Line of Credit Facility [Line Items] | |
Total | 1,400,000,000 |
Nicor Gas | |
Line of Credit Facility [Line Items] | |
Total | $ 500,000,000 |
Financing - Schedule of Long-Te
Financing - Schedule of Long-Term Debt Financing Activities (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2018USD ($) | |
Debt Instrument [Line Items] | |
Senior Note Issuances | $ 1,850 |
Senior Note Maturities, Redemptions, and Repurchases | 2,350 |
Revenue Bond Maturities, Redemptions, and Repurchases | 712 |
Other Long-Term Debt Issuances | 100 |
Other Long-Term Debt Redemptions and Maturities | 1,436 |
Elimination | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 0 |
Senior Note Maturities, Redemptions, and Repurchases | 0 |
Revenue Bond Maturities, Redemptions, and Repurchases | 0 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | (1) |
ALABAMA POWER CO | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 500 |
Senior Note Maturities, Redemptions, and Repurchases | 0 |
Revenue Bond Maturities, Redemptions, and Repurchases | 0 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | 0 |
GEORGIA POWER CO | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 0 |
Senior Note Maturities, Redemptions, and Repurchases | 1,000 |
Revenue Bond Maturities, Redemptions, and Repurchases | 469 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | 107 |
MISSISSIPPI POWER CO | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 600 |
Senior Note Maturities, Redemptions, and Repurchases | 0 |
Revenue Bond Maturities, Redemptions, and Repurchases | 43 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | 900 |
SOUTHERN POWER CO | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 0 |
Senior Note Maturities, Redemptions, and Repurchases | 350 |
Revenue Bond Maturities, Redemptions, and Repurchases | 0 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | 420 |
SOUTHERN Co GAS | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 0 |
Senior Note Maturities, Redemptions, and Repurchases | 0 |
Revenue Bond Maturities, Redemptions, and Repurchases | 200 |
Other Long-Term Debt Issuances | 100 |
Other Long-Term Debt Redemptions and Maturities | 0 |
Other | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 0 |
Senior Note Maturities, Redemptions, and Repurchases | 0 |
Revenue Bond Maturities, Redemptions, and Repurchases | 0 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | 10 |
Southern Company | |
Debt Instrument [Line Items] | |
Senior Note Issuances | 750 |
Senior Note Maturities, Redemptions, and Repurchases | 1,000 |
Revenue Bond Maturities, Redemptions, and Repurchases | 0 |
Other Long-Term Debt Issuances | 0 |
Other Long-Term Debt Redemptions and Maturities | $ 0 |
Retirement Benefits (Details)
Retirement Benefits (Details) - USD ($) | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Amortization: | ||||
Net (gain)/loss | ||||
Pension Plans | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined benefit plan, expected future employer contributions, remainder of fiscal year | $ 0 | $ 0 | ||
Pension Plans | ALABAMA POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 19,000,000 | 15,000,000 | 58,000,000 | $ 47,000,000 |
Interest cost | 26,000,000 | 25,000,000 | 76,000,000 | 73,000,000 |
Expected return on plan assets | (51,000,000) | (49,000,000) | (155,000,000) | (147,000,000) |
Amortization: | ||||
Prior service costs | 0 | 1,000,000 | 1,000,000 | 2,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 13,000,000 | 10,000,000 | 40,000,000 | 31,000,000 |
Net periodic pension cost (income) | 7,000,000 | 2,000,000 | 20,000,000 | 6,000,000 |
Pension Plans | GEORGIA POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 22,000,000 | 19,000,000 | 65,000,000 | 56,000,000 |
Interest cost | 34,000,000 | 34,000,000 | 104,000,000 | 103,000,000 |
Expected return on plan assets | (74,000,000) | (71,000,000) | (222,000,000) | (212,000,000) |
Amortization: | ||||
Prior service costs | 1,000,000 | 0 | 2,000,000 | 2,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 18,000,000 | 15,000,000 | 52,000,000 | 43,000,000 |
Net periodic pension cost (income) | 1,000,000 | (3,000,000) | 1,000,000 | (8,000,000) |
Pension Plans | GULF POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 4,000,000 | 3,000,000 | 12,000,000 | 10,000,000 |
Interest cost | 5,000,000 | 5,000,000 | 15,000,000 | 15,000,000 |
Expected return on plan assets | (10,000,000) | (10,000,000) | (30,000,000) | (29,000,000) |
Amortization: | ||||
Prior service costs | 0 | 0 | 0 | 0 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 2,000,000 | 2,000,000 | 7,000,000 | 5,000,000 |
Net periodic pension cost (income) | 1,000,000 | 0 | 4,000,000 | 1,000,000 |
Pension Plans | MISSISSIPPI POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 5,000,000 | 4,000,000 | 13,000,000 | 11,000,000 |
Interest cost | 5,000,000 | 5,000,000 | 15,000,000 | 15,000,000 |
Expected return on plan assets | (11,000,000) | (9,000,000) | (31,000,000) | (29,000,000) |
Amortization: | ||||
Prior service costs | 0 | 0 | 0 | 1,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 3,000,000 | 1,000,000 | 8,000,000 | 5,000,000 |
Net periodic pension cost (income) | 2,000,000 | 1,000,000 | 5,000,000 | 3,000,000 |
Pension Plans | SOUTHERN POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 3,000,000 | 7,000,000 | ||
Interest cost | 1,000,000 | 4,000,000 | ||
Expected return on plan assets | (3,000,000) | (8,000,000) | ||
Amortization: | ||||
Prior service costs | 0 | 0 | ||
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 0 | 1,000,000 | ||
Net periodic pension cost (income) | 1,000,000 | 4,000,000 | ||
Pension Plans | SOUTHERN Co GAS | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 8,000,000 | 6,000,000 | 24,000,000 | 17,000,000 |
Interest cost | 10,000,000 | 10,000,000 | 29,000,000 | 30,000,000 |
Expected return on plan assets | (18,000,000) | (18,000,000) | (53,000,000) | (53,000,000) |
Amortization: | ||||
Prior service costs | (1,000,000) | 0 | (2,000,000) | (1,000,000) |
Regulatory asset | 4,000,000 | 11,000,000 | ||
Net (gain)/loss | 3,000,000 | 5,000,000 | 9,000,000 | 15,000,000 |
Net periodic pension cost (income) | 6,000,000 | 3,000,000 | 18,000,000 | 8,000,000 |
Pension Plans | Southern Company | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 90,000,000 | 73,000,000 | 269,000,000 | 220,000,000 |
Interest cost | 116,000,000 | 114,000,000 | 348,000,000 | 341,000,000 |
Expected return on plan assets | (236,000,000) | (224,000,000) | (707,000,000) | (673,000,000) |
Amortization: | ||||
Prior service costs | 1,000,000 | 3,000,000 | 3,000,000 | 9,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 53,000,000 | 41,000,000 | 160,000,000 | 122,000,000 |
Net periodic pension cost (income) | 24,000,000 | 7,000,000 | 73,000,000 | 19,000,000 |
Postretirement Benefits | ALABAMA POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 1,000,000 | 1,000,000 | 4,000,000 | 4,000,000 |
Interest cost | 5,000,000 | 4,000,000 | 13,000,000 | 13,000,000 |
Expected return on plan assets | (7,000,000) | (5,000,000) | (20,000,000) | (19,000,000) |
Amortization: | ||||
Prior service costs | 1,000,000 | 1,000,000 | 3,000,000 | 3,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 0 | 0 | 1,000,000 | 1,000,000 |
Net periodic pension cost (income) | 0 | 1,000,000 | 1,000,000 | 2,000,000 |
Postretirement Benefits | GEORGIA POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 2,000,000 | 2,000,000 | 5,000,000 | 5,000,000 |
Interest cost | 7,000,000 | 6,000,000 | 21,000,000 | 21,000,000 |
Expected return on plan assets | (6,000,000) | (6,000,000) | (19,000,000) | (18,000,000) |
Amortization: | ||||
Prior service costs | 0 | 0 | 1,000,000 | 1,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 2,000,000 | 3,000,000 | 6,000,000 | 6,000,000 |
Net periodic pension cost (income) | 5,000,000 | 5,000,000 | 14,000,000 | 15,000,000 |
Postretirement Benefits | GULF POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 0 | 0 | 1,000,000 | 1,000,000 |
Interest cost | 1,000,000 | 1,000,000 | 2,000,000 | 2,000,000 |
Expected return on plan assets | 0 | 0 | (1,000,000) | (1,000,000) |
Amortization: | ||||
Prior service costs | 0 | 0 | 0 | 0 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 0 | 0 | 0 | 0 |
Net periodic pension cost (income) | 1,000,000 | 1,000,000 | 2,000,000 | 2,000,000 |
Postretirement Benefits | MISSISSIPPI POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 0 | 0 | 1,000,000 | 1,000,000 |
Interest cost | 0 | 1,000,000 | 2,000,000 | 3,000,000 |
Expected return on plan assets | 0 | 0 | (1,000,000) | (1,000,000) |
Amortization: | ||||
Prior service costs | 0 | 0 | 0 | 0 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 0 | 0 | 0 | 0 |
Net periodic pension cost (income) | 0 | 1,000,000 | 2,000,000 | 3,000,000 |
Postretirement Benefits | SOUTHERN POWER CO | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 1,000,000 | 1,000,000 | ||
Interest cost | 0 | 0 | ||
Expected return on plan assets | 0 | 0 | ||
Amortization: | ||||
Prior service costs | 0 | 0 | ||
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 0 | 0 | ||
Net periodic pension cost (income) | 1,000,000 | 1,000,000 | ||
Postretirement Benefits | SOUTHERN Co GAS | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 0 | 1,000,000 | 1,000,000 | 2,000,000 |
Interest cost | 2,000,000 | 3,000,000 | 7,000,000 | 8,000,000 |
Expected return on plan assets | (1,000,000) | (2,000,000) | (5,000,000) | (5,000,000) |
Amortization: | ||||
Prior service costs | 0 | (1,000,000) | 0 | (2,000,000) |
Regulatory asset | 2,000,000 | 5,000,000 | ||
Net (gain)/loss | 0 | 1,000,000 | 0 | 3,000,000 |
Net periodic pension cost (income) | 3,000,000 | 2,000,000 | 8,000,000 | 6,000,000 |
Postretirement Benefits | Southern Company | ||||
Pension Plans and Postretirement Plans | ||||
Service cost | 6,000,000 | 6,000,000 | 18,000,000 | 18,000,000 |
Interest cost | 19,000,000 | 19,000,000 | 56,000,000 | 59,000,000 |
Expected return on plan assets | (17,000,000) | (16,000,000) | (51,000,000) | (49,000,000) |
Amortization: | ||||
Prior service costs | 2,000,000 | 2,000,000 | 5,000,000 | 5,000,000 |
Regulatory asset | 0 | 0 | ||
Net (gain)/loss | 3,000,000 | 3,000,000 | 10,000,000 | 10,000,000 |
Net periodic pension cost (income) | $ 13,000,000 | $ 14,000,000 | $ 38,000,000 | $ 43,000,000 |
Income Taxes - Narrative (Detai
Income Taxes - Narrative (Details) | Apr. 03, 2018 | Sep. 30, 2018USD ($) | Dec. 31, 2018operating_facility | Sep. 30, 2018USD ($) | Jun. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Jun. 30, 2018USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Dec. 31, 2019 | Dec. 31, 2017USD ($) |
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | $ 190,000,000 | $ 190,000,000 | $ 190,000,000 | $ 148,000,000 | |||||||
Effective tax rate decrease | 14.00% | ||||||||||
Effective tax (benefit) rate | 22.70% | 42.60% | |||||||||
Increase in effective tax rate due to loss on Kemper IGCC | $ 3,100,000,000 | ||||||||||
Impairment charges | 36,000,000 | $ 0 | $ 197,000,000 | 0 | |||||||
Income taxes benefit | (623,000,000) | (590,000,000) | (598,000,000) | $ (317,000,000) | |||||||
Unrecognized tax benefits | 0 | 0 | $ 0 | ||||||||
Significantly increase (decrease) in amount of unrecognized tax benefits | 12 months | ||||||||||
State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 171,000,000 | 171,000,000 | $ 171,000,000 | ||||||||
ALABAMA POWER CO | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Effective tax (benefit) rate | 23.90% | 39.90% | |||||||||
Income taxes benefit | (127,000,000) | (216,000,000) | $ (272,000,000) | $ (493,000,000) | |||||||
GEORGIA POWER CO | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 39,000,000 | 39,000,000 | $ 39,000,000 | ||||||||
Effective tax (benefit) rate | 25.50% | 37.00% | |||||||||
Income taxes benefit | (262,000,000) | (350,000,000) | $ (212,000,000) | $ (705,000,000) | |||||||
GEORGIA POWER CO | Plant Vogtle Units 3 And 4 | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Estimated project costs | $ 1,100,000,000 | ||||||||||
GEORGIA POWER CO | State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 33,000,000 | 33,000,000 | $ 33,000,000 | ||||||||
Effective tax (benefit) rate | 6.00% | ||||||||||
GEORGIA POWER CO | Scenario, Forecast | State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Effective tax (benefit) rate | 5.75% | ||||||||||
GULF POWER CO | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Effective tax (benefit) rate | (0.50%) | 39.40% | |||||||||
Income taxes benefit | 4,000,000 | (40,000,000) | $ 1,000,000 | $ (78,000,000) | |||||||
MISSISSIPPI POWER CO | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 124,000,000 | 124,000,000 | $ 124,000,000 | ||||||||
Effective tax (benefit) rate | 20.80% | (30.30%) | |||||||||
Increase in effective tax rate due to loss on Kemper IGCC | $ 3,100,000,000 | ||||||||||
Income taxes benefit | (14,000,000) | (24,000,000) | (23,000,000) | $ 885,000,000 | |||||||
MISSISSIPPI POWER CO | State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 124,000,000 | 124,000,000 | $ 124,000,000 | ||||||||
SOUTHERN POWER CO | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Effective tax (benefit) rate | (220.30%) | (66.50%) | |||||||||
Impairment charges | 36,000,000 | 0 | $ 155,000,000 | $ 0 | |||||||
Income taxes benefit | 38,000,000 | 39,000,000 | $ 54,000,000 | 210,000,000 | $ 129,000,000 | ||||||
SOUTHERN POWER CO | State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Income taxes benefit | 11,000,000 | ||||||||||
SOUTHERN POWER CO | Scenario, Forecast | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Number of operating wind facilities | operating_facility | 8 | ||||||||||
SOUTHERN POWER CO | Florida Plants | Disposal Group, Held-for-sale, Not Discontinued Operations | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Pre-tax impairment charge | 119,000,000 | ||||||||||
Impairment charges | 36,000,000 | ||||||||||
SOUTHERN Co GAS | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 12,000,000 | 12,000,000 | $ 12,000,000 | ||||||||
Effective tax (benefit) rate | 61.80% | 43.40% | |||||||||
Income taxes benefit | (316,000,000) | $ (52,000,000) | $ (475,000,000) | $ (233,000,000) | |||||||
SOUTHERN Co GAS | State | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Valuation allowances | 1,000,000 | 1,000,000 | 1,000,000 | ||||||||
Investment Tax Credit Carryforward | |||||||||||
Income Tax Contingency [Line Items] | |||||||||||
Tax credit carryforward, amount | $ 2,400,000,000 | $ 2,400,000,000 | $ 2,400,000,000 | $ 2,100,000,000 |
Income Taxes - Summary of Valua
Income Taxes - Summary of Valuation Allowances (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Valuation Allowance [Line Items] | ||
Valuation allowances | $ 190 | $ 148 |
Federal | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 19 | |
State (net of federal benefit) | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 171 | |
GEORGIA POWER CO | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 39 | |
GEORGIA POWER CO | Federal | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 6 | |
GEORGIA POWER CO | State (net of federal benefit) | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 33 | |
MISSISSIPPI POWER CO | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 124 | |
MISSISSIPPI POWER CO | Federal | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 0 | |
MISSISSIPPI POWER CO | State (net of federal benefit) | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 124 | |
SOUTHERN Co GAS | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 12 | |
SOUTHERN Co GAS | Federal | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | 11 | |
SOUTHERN Co GAS | State (net of federal benefit) | ||
Valuation Allowance [Line Items] | ||
Valuation allowances | $ 1 |
Derivatives - Energy-Related an
Derivatives - Energy-Related and Interest Rate Derivatives (Details) MMBTU in Millions | 9 Months Ended |
Sep. 30, 2018USD ($)MMBTU | |
Energy-related, Natural Gas | ALABAMA POWER CO | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 82 |
Longest Hedge Date | 2,022 |
Energy-related, Natural Gas | GEORGIA POWER CO | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 165 |
Longest Hedge Date | 2,022 |
Energy-related, Natural Gas | GULF POWER CO | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 9 |
Longest Hedge Date | 2,020 |
Energy-related, Natural Gas | MISSISSIPPI POWER CO | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 69 |
Longest Hedge Date | 2,022 |
Energy-related, Natural Gas | SOUTHERN POWER CO | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 15 |
Longest Hedge Date | 2,020 |
Energy-related, Natural Gas | SOUTHERN Co GAS | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 255 |
Longest Hedge Date | 2,021 |
Longest Non-Hedge Date | 2,029 |
Energy-related, Natural Gas | SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Long | |
Energy-related derivative contracts | |
Derivative nonmonetary notional amount net long short position volume | MMBTU | 4,300 |
Energy-related, Natural Gas | SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Short | |
Energy-related derivative contracts | |
Derivative nonmonetary notional amount net long short position volume | MMBTU | 4,000 |
Energy-related, Natural Gas | Southern Company | |
Energy-related derivative contracts | |
Net Purchased mmBtu | MMBTU | 595 |
Longest Hedge Date | 2,022 |
Longest Non-Hedge Date | 2,029 |
Interest rate derivatives | |
Interest rate derivatives | |
Notional Amount | $ 2,500,000,000 |
Fair Value Gain (Loss) at September 30, 2018 | (72,000,000) |
Interest rate derivatives | GEORGIA POWER CO | December 2018 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Notional Amount | $ 500,000,000 |
Interest Rate Received | 1.95% |
Fair Value Gain (Loss) at September 30, 2018 | $ (3,000,000) |
Interest rate derivatives | GEORGIA POWER CO | December 2019 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Notional Amount | $ 200,000,000 |
Interest Rate Received | 4.25% |
Fair Value Gain (Loss) at September 30, 2018 | $ (3,000,000) |
Interest rate derivatives | Southern Company | June 2020 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Notional Amount | $ 300,000,000 |
Interest Rate Received | 2.75% |
Fair Value Gain (Loss) at September 30, 2018 | $ (6,000,000) |
Interest rate derivatives | Southern Company | July 2021 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Notional Amount | $ 1,500,000,000 |
Interest Rate Received | 2.35% |
Fair Value Gain (Loss) at September 30, 2018 | $ (60,000,000) |
LIBOR | Interest rate derivatives | GEORGIA POWER CO | December 2018 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Weighted Average Interest Rate Paid | 0.76% |
LIBOR | Interest rate derivatives | GEORGIA POWER CO | December 2019 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Weighted Average Interest Rate Paid | 2.46% |
LIBOR | Interest rate derivatives | Southern Company | June 2020 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Weighted Average Interest Rate Paid | 0.92% |
LIBOR | Interest rate derivatives | Southern Company | July 2021 | Fair Value Hedges of Existing Debt | |
Interest rate derivatives | |
Weighted Average Interest Rate Paid | 0.87% |
Derivatives - Narrative (Detail
Derivatives - Narrative (Details) MMBTU in Millions | 9 Months Ended | |
Sep. 30, 2018USD ($)MMBTU | Dec. 31, 2017USD ($) | |
Derivative [Line Items] | ||
Collateral already posted, aggregate fair value | $ | $ 189,000,000 | |
ALABAMA POWER CO | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 2 | |
GEORGIA POWER CO | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 4 | |
Gulf Power and Mississippi Power | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 1 | |
MISSISSIPPI POWER CO | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 2 | |
SOUTHERN POWER CO | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 4 | |
Parent Company and Southern Power | ||
Derivative [Line Items] | ||
Foreign currency cash flow hedge gain (loss) to be reclassified during next 12 months | $ | $ (23,000,000) | |
Registrants | Derivative Counterparties | ||
Derivative [Line Items] | ||
Collateral already posted, aggregate fair value | $ | 0 | |
SOUTHERN Co GAS | ||
Derivative [Line Items] | ||
Collateral already posted, aggregate fair value | $ | $ 189,000,000 | $ 193,000,000 |
Southern Company | ||
Derivative [Line Items] | ||
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | 13 | |
Cash flow hedge gain (loss) to be reclassified within twelve months | $ | $ (19,000,000) |
Derivatives - Foreign Currency
Derivatives - Foreign Currency Derivatives (Details) - 9 months ended Sep. 30, 2018 - Cash Flow Hedges of Existing Debt - Foreign currency derivatives € in Millions, $ in Millions | USD ($) | EUR (€) |
Derivative [Line Items] | ||
Pay Notional | $ 1,241 | |
Receive Notional | € | € 1,100 | |
Fair Value Gain (Loss) at September 30, 2018 | 99 | |
SOUTHERN POWER CO | June 2022 | ||
Derivative [Line Items] | ||
Pay Notional | $ 677 | |
Pay Rate | 2.95% | |
Receive Notional | € | 600 | |
Receive Rate | 1.00% | |
Fair Value Gain (Loss) at September 30, 2018 | $ 48 | |
SOUTHERN POWER CO | June 2026 | ||
Derivative [Line Items] | ||
Pay Notional | $ 564 | |
Pay Rate | 3.78% | |
Receive Notional | € | € 500 | |
Receive Rate | 1.85% | |
Fair Value Gain (Loss) at September 30, 2018 | $ 51 |
Derivatives - Derivative Financ
Derivatives - Derivative Financial Statement Presentation and Amounts With Balance Sheet Offsetting (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Derivatives, Fair Value [Line Items] | ||
Collateral already posted, aggregate fair value | $ 189 | |
Southern Company | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 543 | $ 700 |
Derivatives, liabilities | 668 | 794 |
Derivative asset, Gross amounts offset | (303) | (405) |
Derivative liability, Gross amounts offset | (491) | (598) |
Derivative asset | 240 | 295 |
Derivative liability | 177 | 196 |
Southern Company | Derivatives not designated as hedging instruments | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 397 | 550 |
Derivatives, liabilities | 515 | 652 |
Southern Company | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 263 | 380 |
Southern Company | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 317 | 437 |
Southern Company | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 134 | 170 |
Southern Company | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 198 | 215 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 20 | 17 |
Derivatives, liabilities | 51 | 67 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 15 | 10 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 17 | 43 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 5 | 7 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 26 | 24 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets held for sale, current | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities held for sale, current | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 0 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets held for sale | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities held for sale | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 2 | 0 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 126 | 133 |
Derivatives, liabilities | 102 | 75 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 3 | 3 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 14 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 1 | 0 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 1 | 0 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 1 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 22 | 4 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 50 | 34 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 23 | 23 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 122 | 129 |
Southern Company | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 0 | 0 |
ALABAMA POWER CO | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 7 | 4 |
Derivatives, liabilities | 10 | 10 |
Derivative asset, Gross amounts offset | (4) | (4) |
Derivative liability, Gross amounts offset | (4) | (4) |
Derivative asset | 3 | 0 |
Derivative liability | 6 | 6 |
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 7 | 4 |
Derivatives, liabilities | 10 | 10 |
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 5 | 2 |
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 4 | 6 |
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 2 | 2 |
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 4 |
GEORGIA POWER CO | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 7 | 6 |
Derivatives, liabilities | 28 | 24 |
Derivative asset, Gross amounts offset | (7) | (6) |
Derivative liability, Gross amounts offset | (7) | (6) |
Derivative asset | 0 | 0 |
Derivative liability | 21 | 18 |
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 7 | 6 |
Derivatives, liabilities | 22 | 19 |
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 5 | 2 |
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 9 | 9 |
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 2 | 4 |
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 13 | 10 |
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Derivatives, liabilities | 6 | 5 |
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 5 | 4 |
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 1 | 1 |
GULF POWER CO | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Derivatives, liabilities | 8 | 21 |
Derivative asset | 0 | 0 |
Derivative liability | 8 | 21 |
GULF POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
Derivatives, liabilities | 8 | 21 |
GULF POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
GULF POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 14 |
GULF POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
GULF POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 2 | 7 |
MISSISSIPPI POWER CO | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 3 | 3 |
Derivatives, liabilities | 9 | 9 |
Derivative asset, Gross amounts offset | (3) | (2) |
Derivative liability, Gross amounts offset | (3) | (2) |
Derivative asset | 0 | 1 |
Derivative liability | 6 | 7 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 3 | 2 |
Derivatives, liabilities | 9 | 9 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 2 | 1 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 3 | 6 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 1 | 1 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 3 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 1 |
Derivatives, liabilities | 0 | 0 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 1 |
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 0 | 0 |
SOUTHERN POWER CO | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 125 | 132 |
Derivatives, liabilities | 30 | 36 |
Derivative asset, Gross amounts offset | (2) | (3) |
Derivative liability, Gross amounts offset | (2) | (3) |
Derivative asset | 123 | 129 |
Derivative liability | 28 | 33 |
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 0 | 2 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 125 | 132 |
Derivatives, liabilities | 30 | 34 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 2 | 3 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 6 | 11 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 1 | 0 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 1 | 0 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 23 | 23 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 122 | 129 |
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 0 | 0 |
SOUTHERN Co GAS | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 400 | 554 |
Derivatives, liabilities | 516 | 660 |
Derivative asset, Gross amounts offset | (287) | (390) |
Derivative liability, Gross amounts offset | (475) | (583) |
Derivative asset | 113 | 164 |
Derivative liability | 41 | 77 |
Collateral already posted, aggregate fair value | 189 | 193 |
Weather derivative premium | 5 | 11 |
SOUTHERN Co GAS | Energy-related derivatives | ||
Derivatives, Fair Value [Line Items] | ||
Collateral already posted, aggregate fair value | 3 | 6 |
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 396 | 549 |
Derivatives, liabilities | 514 | 649 |
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 134 | 170 |
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 198 | 215 |
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 262 | 379 |
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Liabilities from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 316 | 434 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 3 | 5 |
Derivatives, liabilities | 2 | 8 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 0 | 0 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 1 | 0 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 3 | 5 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | 1 | 8 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, assets | 1 | 0 |
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities from risk management activities | ||
Derivatives, Fair Value [Line Items] | ||
Derivatives, liabilities | $ 0 | $ 3 |
Derivatives - Pre-tax Effects o
Derivatives - Pre-tax Effects of Derivatives Designated as Cash Flow Hedging Instruments (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | Dec. 31, 2017 | |
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Collateral already posted, aggregate fair value | $ 189 | $ 189 | |||
Gain (Loss) Recognized in OCI on Derivative | (15) | $ 39 | (26) | $ 86 | |
SOUTHERN POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Gain (Loss) Recognized in OCI on Derivative | (15) | 40 | (26) | 93 | |
SOUTHERN Co GAS | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Collateral already posted, aggregate fair value | 189 | 189 | $ 193 | ||
Energy-related derivatives | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (29) | (29) | (44) | ||
Gain (Loss) Recognized in OCI on Derivative | (5) | (6) | 7 | (26) | |
Energy-related derivatives | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (9) | (9) | (34) | ||
Energy-related derivatives | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (20) | (20) | (18) | ||
Energy-related derivatives | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (6) | (6) | |||
Energy-related derivatives | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (2) | (2) | |||
Energy-related derivatives | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 8 | 8 | 7 | ||
Energy-related derivatives | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 1 | ||||
Energy-related derivatives | ALABAMA POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (3) | (3) | (6) | ||
Energy-related derivatives | ALABAMA POWER CO | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (2) | (2) | (4) | ||
Energy-related derivatives | ALABAMA POWER CO | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (4) | (4) | (3) | ||
Energy-related derivatives | ALABAMA POWER CO | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | ALABAMA POWER CO | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | ALABAMA POWER CO | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 3 | 3 | 0 | ||
Energy-related derivatives | ALABAMA POWER CO | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 1 | ||||
Energy-related derivatives | GEORGIA POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (15) | (15) | (13) | ||
Energy-related derivatives | GEORGIA POWER CO | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (4) | (4) | (7) | ||
Energy-related derivatives | GEORGIA POWER CO | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (11) | (11) | (6) | ||
Energy-related derivatives | GEORGIA POWER CO | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | GEORGIA POWER CO | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | GEORGIA POWER CO | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | 0 | ||
Energy-related derivatives | GEORGIA POWER CO | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | ||||
Energy-related derivatives | GULF POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (8) | (8) | (21) | ||
Energy-related derivatives | GULF POWER CO | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (6) | (6) | (14) | ||
Energy-related derivatives | GULF POWER CO | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (2) | (2) | (7) | ||
Energy-related derivatives | GULF POWER CO | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | GULF POWER CO | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | GULF POWER CO | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | 0 | ||
Energy-related derivatives | GULF POWER CO | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | ||||
Energy-related derivatives | MISSISSIPPI POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (7) | (7) | (7) | ||
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (2) | (2) | (5) | ||
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (5) | (5) | (2) | ||
Energy-related derivatives | MISSISSIPPI POWER CO | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | MISSISSIPPI POWER CO | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | 0 | ||
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | ||||
Energy-related derivatives | SOUTHERN POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Gain (Loss) Recognized in OCI on Derivative | (5) | (6) | 5 | (21) | |
Energy-related derivatives | SOUTHERN Co GAS | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 4 | 4 | 3 | ||
Collateral already posted, aggregate fair value | 3 | 3 | 6 | ||
Gain (Loss) Recognized in OCI on Derivative | 0 | 0 | 2 | (4) | |
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory assets, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | (1) | (1) | (4) | ||
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory assets, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | 0 | ||
Energy-related derivatives | SOUTHERN Co GAS | Assets held for sale, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | SOUTHERN Co GAS | Assets held for sale | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 0 | 0 | |||
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory liabilities, current | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | 5 | 5 | 7 | ||
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory liabilities, deferred | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Total energy-related derivative gains (losses) | $ 0 | ||||
Interest rate derivatives | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Gain (Loss) Recognized in OCI on Derivative | 0 | (1) | (2) | (2) | |
Foreign currency derivatives | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Gain (Loss) Recognized in OCI on Derivative | (10) | 46 | (31) | 114 | |
Foreign currency derivatives | SOUTHERN POWER CO | |||||
Derivative Instruments, Gain (Loss) [Line Items] | |||||
Gain (Loss) Recognized in OCI on Derivative | $ (10) | $ 46 | $ (31) | $ 114 |
Derivatives - Location and Amou
Derivatives - Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Derivative [Line Items] | ||||
Cost of natural gas | $ 104 | $ 134 | $ 1,053 | $ 1,085 |
Gain (loss) recognized in income | (15) | 39 | (26) | 86 |
Depreciation and amortization | 787 | 767 | 2,338 | 2,236 |
Interest expense, net of amounts capitalized | (458) | (407) | (1,386) | (1,248) |
Other income (expense), net | 57 | 65 | 195 | 165 |
Energy-related derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (5) | (6) | 7 | (26) |
Interest rate derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | (1) | (2) | (2) |
Foreign currency derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (10) | 46 | (31) | 114 |
Cash Flow Hedging | Energy-related derivatives | Cost of natural gas | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | 0 | (2) | 0 |
Cash Flow Hedging | Energy-related derivatives | Depreciation and amortization | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | (6) | 2 | (12) |
Cash Flow Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (5) | (5) | (16) | (15) |
Cash Flow Hedging | Foreign currency derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (6) | (5) | (18) | (17) |
Cash Flow Hedging | Foreign currency derivatives | Other income (expense), net | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (9) | 43 | (46) | 139 |
Fair Value Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (4) | (5) | (35) | (6) |
ALABAMA POWER CO | ||||
Derivative [Line Items] | ||||
Depreciation and amortization | 192 | 185 | 570 | 549 |
Interest expense, net of amounts capitalized | (82) | (76) | (240) | (229) |
Other income (expense), net | 9 | 10 | 24 | 35 |
ALABAMA POWER CO | Cash Flow Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (1) | (2) | (4) | (5) |
GEORGIA POWER CO | ||||
Derivative [Line Items] | ||||
Depreciation and amortization | 232 | 225 | 690 | 669 |
Interest expense, net of amounts capitalized | (95) | (105) | (303) | (310) |
Other income (expense), net | 30 | 22 | 104 | 95 |
GEORGIA POWER CO | Cash Flow Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (1) | (1) | (4) | (3) |
GEORGIA POWER CO | Fair Value Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | 0 | (1) | (1) |
MISSISSIPPI POWER CO | ||||
Derivative [Line Items] | ||||
Depreciation and amortization | 42 | 39 | 126 | 120 |
Interest expense, net of amounts capitalized | (19) | 13 | (59) | (23) |
Other income (expense), net | 0 | 1 | 28 | 4 |
MISSISSIPPI POWER CO | Cash Flow Hedging | Interest rate derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | 0 | (1) | (1) |
SOUTHERN POWER CO | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (15) | 40 | (26) | 93 |
Depreciation and amortization | 130 | 131 | 370 | 379 |
Interest expense, net of amounts capitalized | (45) | (47) | (138) | (144) |
Other income (expense), net | 17 | 3 | 22 | 3 |
SOUTHERN POWER CO | Energy-related derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (5) | (6) | 5 | (21) |
SOUTHERN POWER CO | Foreign currency derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (10) | 46 | (31) | 114 |
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives | Depreciation and amortization | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | (6) | 2 | (12) |
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Interest expense, net of amounts capitalized | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (6) | (5) | (18) | (17) |
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Other income (expense), net | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | (9) | 43 | (46) | 139 |
SOUTHERN Co GAS | ||||
Derivative [Line Items] | ||||
Cost of natural gas | 104 | 134 | 1,053 | 1,085 |
Depreciation and amortization | 119 | 125 | 374 | 370 |
Interest expense, net of amounts capitalized | (52) | (51) | (170) | (145) |
Other income (expense), net | 6 | 19 | 21 | 30 |
SOUTHERN Co GAS | Energy-related derivatives | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | 0 | 0 | 2 | (4) |
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives | Cost of natural gas | ||||
Derivative [Line Items] | ||||
Gain (loss) recognized in income | $ 0 | $ 0 | $ (2) | $ 0 |
Derivatives - Cumulative Basis
Derivatives - Cumulative Basis Adjustments for Fair Value Hedges (Details) - Fair Value Hedging - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Securities due within one year | ||
Derivative [Line Items] | ||
Carrying Amount of the Hedged Item | $ (499) | $ (746) |
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item | 1 | 3 |
Securities due within one year | GEORGIA POWER CO | ||
Derivative [Line Items] | ||
Carrying Amount of the Hedged Item | (499) | (746) |
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item | 1 | 3 |
Long-term debt | ||
Derivative [Line Items] | ||
Carrying Amount of the Hedged Item | (2,526) | (2,553) |
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item | 65 | 35 |
Long-term debt | GEORGIA POWER CO | ||
Derivative [Line Items] | ||
Carrying Amount of the Hedged Item | (497) | (498) |
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item | $ 2 | $ 1 |
Derivatives - Pre-tax Effects_2
Derivatives - Pre-tax Effects of Derivatives Not Designated as Hedging (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
SOUTHERN Co GAS | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative, gain (loss) on derivative, net | $ (23) | $ 32 | ||
Weather Derivatives | Southern Company | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative, gain (loss) on derivative, net | $ 0 | $ 0 | 0 | 15 |
Derivatives not designated as hedging instruments | Energy-related derivatives | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | (34) | (15) | (74) | 46 |
Derivatives not designated as hedging instruments | Energy-related derivatives | Natural gas revenues | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | (36) | (17) | (79) | 48 |
Derivatives not designated as hedging instruments | Energy-related derivatives | Cost of natural gas | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | 2 | 2 | 5 | (2) |
Derivatives not designated as hedging instruments | Energy-related derivatives | SOUTHERN Co GAS | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | (34) | (15) | (74) | 46 |
Derivatives not designated as hedging instruments | Energy-related derivatives | SOUTHERN Co GAS | Natural gas revenues | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | (36) | (17) | (79) | 48 |
Derivatives not designated as hedging instruments | Energy-related derivatives | SOUTHERN Co GAS | Cost of natural gas | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Derivative instruments not designated as hedging instruments, gain (loss), net | $ 2 | $ 2 | $ 5 | $ (2) |
Acquisitions and Dispositions -
Acquisitions and Dispositions - Southern Company (Details) - Scenario, Forecast - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2019 | Jun. 28, 2019 | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Stock purchase agreement, contract termination fees | $ 100 | |
700 Universe, LLC | Minimum | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Stock purchase agreement, contract termination fees | 100 | |
700 Universe, LLC | Maximum | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Stock purchase agreement, contract termination fees | $ 200 | |
Disposal Group, Disposed of by Sale, Not Discontinued Operations | GULF POWER CO | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Proceeds from divestiture of businesses, net of cash divested | $ 5,750 | |
Amount of indebtedness assumed at closing | $ 1,300 |
Acquisitions and Dispositions_2
Acquisitions and Dispositions - Schedule of Business Acquisitions and Construction Projects (Details) - SOUTHERN POWER CO - MW | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||||||
Jul. 31, 2018 | Mar. 31, 2018 | Jun. 30, 2020 | Dec. 31, 2019 | Jun. 30, 2019 | Sep. 30, 2018 | Aug. 31, 2018 | May 31, 2018 | Jul. 31, 2017 | |
Gaskell West 1 | |||||||||
Business Acquisition [Line Items] | |||||||||
Approximate Nameplate Capacity (MW) | 20 | ||||||||
PPA Contract Period | 20 years | ||||||||
Gaskell West 1 | Gaskell West 1 | Common Class B | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Gaskell West 1 | Gaskell West 1 | Class B Membership Interest | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Cactus Flats | |||||||||
Business Acquisition [Line Items] | |||||||||
Approximate Nameplate Capacity (MW) | 148 | ||||||||
Cactus Flats | Minimum | |||||||||
Business Acquisition [Line Items] | |||||||||
PPA Contract Period | 12 years | ||||||||
Cactus Flats | Maximum | |||||||||
Business Acquisition [Line Items] | |||||||||
PPA Contract Period | 15 years | ||||||||
Cactus Flats | Cactus Flats | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Cactus Flats | Cactus Flats | Class B Membership Interest | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Mankato | Scenario, Forecast | |||||||||
Business Acquisition [Line Items] | |||||||||
Approximate Nameplate Capacity (MW) | 385 | ||||||||
PPA Contract Period | 20 years | ||||||||
Wild Horse Mountain | Scenario, Forecast | |||||||||
Business Acquisition [Line Items] | |||||||||
Approximate Nameplate Capacity (MW) | 100 | ||||||||
PPA Contract Period | 20 years | ||||||||
Wild Horse Mountain | Wild Horse Mountain | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Wild Horse Mountain | Wild Horse Mountain | Class B Membership Interest | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Reading | Scenario, Forecast | |||||||||
Business Acquisition [Line Items] | |||||||||
Approximate Nameplate Capacity (MW) | 200 | ||||||||
PPA Contract Period | 12 years | ||||||||
Reading | Reading | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% | ||||||||
Reading | Reading | Class B Membership Interest | |||||||||
Business Acquisition [Line Items] | |||||||||
Southern Power Percentage Ownership | 100.00% |
Acquisitions and Dispositions_3
Acquisitions and Dispositions - Southern Power Narrative (Details) | 1 Months Ended | 2 Months Ended | 3 Months Ended | 8 Months Ended | 9 Months Ended | 12 Months Ended | 36 Months Ended | ||||
May 31, 2018USD ($) | Dec. 31, 2018USD ($) | Dec. 31, 2018USD ($)operating_facility | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Jun. 30, 2019USD ($)MW | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2017USD ($) | |
Business Acquisition [Line Items] | |||||||||||
Construction work in progress | $ 7,655,000,000 | $ 7,655,000,000 | $ 6,904,000,000 | ||||||||
Impairment charges | 36,000,000 | $ 0 | 197,000,000 | $ 0 | |||||||
Increase (decrease) due to sale of noncontrolling interests | 1,280,000,000 | ||||||||||
Assets subject to lien | 111,717,000,000 | 111,717,000,000 | 111,005,000,000 | ||||||||
Common Stockholders' Equity | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Increase (decrease) due to sale of noncontrolling interests | (410,000,000) | ||||||||||
SOUTHERN POWER CO | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Construction work in progress | 586,000,000 | 586,000,000 | 511,000,000 | ||||||||
Impairment charges | 36,000,000 | $ 0 | 155,000,000 | 0 | |||||||
Repayments of debt | $ 770,000,000 | ||||||||||
Repayments of capital | 250,000,000 | 650,000,000 | $ 0 | ||||||||
Increase (decrease) due to sale of noncontrolling interests | 511,000,000 | ||||||||||
Assets subject to lien | 15,355,000,000 | 15,355,000,000 | $ 15,206,000,000 | ||||||||
SOUTHERN POWER CO | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Number of operating wind facilities | operating_facility | 8 | ||||||||||
SOUTHERN POWER CO | Common Stockholders' Equity | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Increase (decrease) due to sale of noncontrolling interests | (410,000,000) | ||||||||||
SOUTHERN POWER CO | Disposal Group, Held-for-sale, Not Discontinued Operations | Florida Plants | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Impairment charges | 36,000,000 | ||||||||||
Proceeds from sale of equity method investments | 195,000,000 | ||||||||||
Decrease in consideration per day between end of fiscal year and closing | 110,000 | ||||||||||
Increase in consideration per day if closing is prior to end of fiscal year | $ 110,000 | ||||||||||
Pre-tax impairment charge | 119,000,000 | ||||||||||
After tax impairment charge | 89,000,000 | ||||||||||
SOUTHERN POWER CO | Wind Generating Facility | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Impairment charges | 36,000,000 | 155,000,000 | |||||||||
SOUTHERN POWER CO | Wind Generating Facility | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Project qualification for production tax credits, percentage | 80.00% | 100.00% | |||||||||
SOUTHERN POWER CO | SP Solar Holdings I, LP | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Limited liability company or limited partnership, members or limited partners, ownership interest | 33.00% | ||||||||||
Proceeds from sale of equity method investments | $ 1,200,000,000 | ||||||||||
SOUTHERN POWER CO | Series of Construction Projects | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Construction work in progress | 246,000,000 | 246,000,000 | |||||||||
SOUTHERN POWER CO | Series of Construction Projects | Minimum | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Estimated future construction payments | 575,000,000 | 575,000,000 | |||||||||
SOUTHERN POWER CO | Series of Construction Projects | Maximum | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Estimated future construction payments | 640,000,000 | 640,000,000 | |||||||||
SOUTHERN POWER CO | Plant Mankato | Senior Lien | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Assets subject to lien | $ 500,000,000 | $ 500,000,000 | |||||||||
SOUTHERN POWER CO | Plant Mankato | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Expansion currently under construction (MW) | MW | 385 | ||||||||||
Tax Equity Funding | SOUTHERN POWER CO | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Repayments of capital | $ 1,000,000,000 | ||||||||||
Tax equity funding | $ 1,200,000,000 | $ 1,200,000,000 | |||||||||
Subsequent Event | SOUTHERN POWER CO | Disposal Group, Held-for-sale, Not Discontinued Operations | Plant Mankato | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Proceeds from sale of equity method investments | $ 650,000,000 | ||||||||||
Decrease per day after June 1, 2019 | 66,667 | ||||||||||
Maximum price decrease | $ 15,000,000 | ||||||||||
Subsequent Event | SOUTHERN POWER CO | Plant Mankato | Scenario, Forecast | |||||||||||
Business Acquisition [Line Items] | |||||||||||
Expansion currently under construction (MW) | MW | 385 |
Acquisitions and Dispositions_4
Acquisitions and Dispositions - Southern Company Gas (Details) $ in Millions | Jul. 29, 2018USD ($) | Jul. 01, 2018USD ($)utility | Jun. 04, 2018USD ($) | Sep. 30, 2018USD ($) | Mar. 31, 2018USD ($) | Sep. 30, 2017USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2017USD ($) | Jul. 31, 2018utility |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Goodwill impairment | $ 42 | ||||||||
Gain on disposition of business | 324 | $ 22 | |||||||
SOUTHERN Co GAS | |||||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Goodwill impairment | $ 0 | $ 42 | $ 0 | 42 | $ 0 | ||||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | |||||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Number of natural gas distribution utilities disposed | utility | 3 | ||||||||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Pivotal Home Solutions | |||||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Cash purchase price on sale of business | $ 365 | ||||||||
Gain (loss) on disposition of business, after tax | (73) | ||||||||
Tax on gain (loss) on disposition of business | $ 39 | ||||||||
Goodwill impairment | $ 42 | $ 42 | |||||||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Elizabethtown Gas and Elkton Gas | |||||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Cash purchase price on sale of business | $ 1,700 | ||||||||
Gain (loss) on disposition of business, after tax | $ 18 | ||||||||
Number of natural gas distribution utilities disposed | utility | 2 | ||||||||
Working capital adjustment | $ 40 | ||||||||
Gain on disposition of business | $ 230 | ||||||||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Florida City Gas | |||||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||||||
Cash purchase price on sale of business | $ 530 | ||||||||
Gain (loss) on disposition of business, after tax | 20 | ||||||||
Gain on disposition of business | 121 | ||||||||
Long-term debt | 3 | ||||||||
Additional cash amount | $ 60 |
Acquisitions and Dispositions_5
Acquisitions and Dispositions - Held for Sale (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Assets Held for Sale: | ||
Current assets | $ 407 | $ 12 |
Liabilities Held for Sale: | ||
Current liabilities | 355 | 0 |
Other non-current liabilities | 2,835 | 0 |
SOUTHERN POWER CO | ||
Assets Held for Sale: | ||
Current assets | 18 | 1 |
Liabilities Held for Sale: | ||
Current liabilities | 4 | $ 0 |
Disposal Group, Held-for-sale, Not Discontinued Operations | ||
Assets Held for Sale: | ||
Current assets | 407 | |
Total property, plant, and equipment | 4,093 | |
Other non-current assets | 574 | |
Total Assets Held for Sale | 5,074 | |
Liabilities Held for Sale: | ||
Current liabilities | 355 | |
Long-term debt | 1,285 | |
Accumulated deferred income taxes | 542 | |
Other non-current liabilities | 1,008 | |
Total Liabilities Held for Sale | 3,190 | |
Disposal Group, Held-for-sale, Not Discontinued Operations | SOUTHERN POWER CO | ||
Assets Held for Sale: | ||
Current assets | 18 | |
Total property, plant, and equipment | 168 | |
Other non-current assets | 17 | |
Total Assets Held for Sale | 203 | |
Liabilities Held for Sale: | ||
Current liabilities | 4 | |
Long-term debt | 0 | |
Accumulated deferred income taxes | 0 | |
Other non-current liabilities | 0 | |
Total Liabilities Held for Sale | $ 4 |
Acquisitions and Dispositions_6
Acquisitions and Dispositions - Pre-tax Profit (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
GULF POWER CO | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Earnings before income taxes | $ 59 | $ 103 | $ 146 | $ 199 |
SOUTHERN POWER CO | Florida Plants | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Earnings before income taxes | $ 18 | $ 11 | $ 40 | $ 28 |
Variable Interest Entity and _3
Variable Interest Entity and Equity Method Investments - Narrative (Details) - USD ($) $ in Millions | 1 Months Ended | 9 Months Ended |
May 31, 2018 | Sep. 30, 2018 | |
SOUTHERN POWER CO | ||
Schedule of Equity Method Investments [Line Items] | ||
Distribution made to limited partner, cash distributions paid, percentage | 67.00% | |
Global Atlantic | ||
Schedule of Equity Method Investments [Line Items] | ||
Distribution made to limited partner, cash distributions paid, percentage | 33.00% | |
SP Solar Holdings I, LP | SOUTHERN POWER CO | ||
Schedule of Equity Method Investments [Line Items] | ||
Limited liability company or limited partnership, members or limited partners, ownership interest | 33.00% | |
SP Solar Holdings I, LP | Wholly Owned Subsidiary Of Southern Power | SOUTHERN POWER CO | ||
Schedule of Equity Method Investments [Line Items] | ||
Ownership interest | 66.00% | |
SP Solar Holdings I, LP | Variable Interest Entity, Primary Beneficiary | SOUTHERN POWER CO | ||
Schedule of Equity Method Investments [Line Items] | ||
Assets | $ 6,400 | |
Liabilities | 111 | |
Noncontrolling interests related to other partners' interests | $ 1,200 | |
SP Solar Holdings I, LP | General Partner | Wholly Owned Subsidiary Of Southern Power | SOUTHERN POWER CO | ||
Schedule of Equity Method Investments [Line Items] | ||
Ownership interest | 1.00% |
Variable Interest Entity and _4
Variable Interest Entity and Equity Method Investments - Balance Sheet Equity Method Investment Carrying Amount (Details) - USD ($) $ in Millions | Sep. 30, 2018 | Dec. 31, 2017 |
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | $ 1,569 | $ 1,513 |
SOUTHERN Co GAS | ||
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | 1,529 | 1,477 |
SOUTHERN Co GAS | SNG | ||
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | 1,260 | 1,262 |
SOUTHERN Co GAS | Atlantic Coast Pipeline | ||
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | 73 | 41 |
SOUTHERN Co GAS | PennEast Pipeline | ||
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | 70 | 57 |
SOUTHERN Co GAS | Other | ||
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | $ 126 | $ 117 |
Variable Interest Entity and _5
Variable Interest Entity and Equity Method Investments - Income Statement Equity Method Investment Carrying Amount (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | $ 36 | $ 32 | $ 108 | $ 100 |
SOUTHERN Co GAS | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | 34 | 32 | 108 | 100 |
SOUTHERN Co GAS | SNG | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | 29 | 28 | 95 | 86 |
SOUTHERN Co GAS | PennEast Pipeline | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | 2 | 1 | 4 | 5 |
SOUTHERN Co GAS | Atlantic Coast Pipeline | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | 1 | 1 | 4 | 4 |
SOUTHERN Co GAS | Other | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Earnings from Equity Method Investments | $ 2 | $ 2 | $ 5 | $ 5 |
Variable Interest Entity and _6
Variable Interest Entity and Equity Method Investments - Investment in SNG (Details) - SNG - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Income Statement Information | ||||
Revenues | $ 145 | $ 146 | $ 451 | $ 445 |
Operating income | 71 | 71 | 230 | 218 |
Net income | $ 58 | $ 57 | $ 190 | $ 172 |
Segment and Related Informati_3
Segment and Related Information - Narrative (Details) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2018USD ($)state | Sep. 30, 2017USD ($) | Sep. 30, 2018USD ($)statesegment | Sep. 30, 2017USD ($) | Jul. 31, 2018utility | |
Segment Reporting Information [Line Items] | |||||
Number of reportable segments | segment | 4 | ||||
Number of states in which entity operates | state | 4 | 4 | |||
Total operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 | |
SOUTHERN Co GAS | |||||
Segment Reporting Information [Line Items] | |||||
Number of reportable segments | segment | 4 | ||||
Number of states in which entity operates | state | 7 | 7 | |||
Total operating revenues | $ 492 | 565 | $ 2,861 | 2,841 | |
SOUTHERN Co GAS | Traditional Electric Operating Companies | |||||
Segment Reporting Information [Line Items] | |||||
Natural gas revenues | 14 | 9 | 22 | 19 | |
SOUTHERN Co GAS | Southern Company | |||||
Segment Reporting Information [Line Items] | |||||
Natural gas revenues | 38 | 38 | 96 | 94 | |
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | |||||
Segment Reporting Information [Line Items] | |||||
Number of natural gas distribution utilities disposed | utility | 3 | ||||
SOUTHERN POWER CO | |||||
Segment Reporting Information [Line Items] | |||||
Total operating revenues | 635 | 618 | 1,699 | 1,597 | |
SOUTHERN POWER CO | Wholesale revenues, affiliates | |||||
Segment Reporting Information [Line Items] | |||||
Total operating revenues | $ 134 | $ 105 | $ 326 | $ 295 |
Segment and Related Informati_4
Segment and Related Information - Financial Data for Business Segments (Details) $ in Millions | 3 Months Ended | 9 Months Ended | |||||
Sep. 30, 2018USD ($)utility | Mar. 31, 2018USD ($) | Sep. 30, 2017USD ($) | Sep. 30, 2018USD ($)utility | Sep. 30, 2017USD ($) | Jul. 31, 2018utility | Dec. 31, 2017USD ($) | |
Segment Reporting Information [Line Items] | |||||||
Operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 | |||
Segment net income (loss) | 1,164 | 1,069 | 1,948 | 347 | |||
Goodwill | 5,315 | 5,315 | $ 6,268 | ||||
Total assets | 111,717 | 111,717 | 111,005 | ||||
Pre-tax impairment charges | 36 | 0 | 197 | 0 | |||
Net gain (loss) on dispositions | 353 | 0 | 317 | 19 | |||
Goodwill impairment | 42 | ||||||
Plant Scherer Unit 3 | |||||||
Segment Reporting Information [Line Items] | |||||||
Loss on Plant Scherer Unit 3 | 33 | ||||||
After tax charge to income | 20 | ||||||
GEORGIA POWER AND MISSISSIPPI POWER CO | Kemper County Energy Facility | |||||||
Segment Reporting Information [Line Items] | |||||||
Public utilities, property, plant and equipment, amount of loss (recovery) on plant abandonment | 1 | 34 | 1,100 | 3,200 | |||
Public utilities, property, plant and equipment, amount of loss (recovery) on plant abandonment after tax | 1 | 21 | 800 | 2,200 | |||
SOUTHERN POWER CO | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 635 | 618 | 1,699 | 1,597 | |||
Segment net income (loss) | 92 | 124 | 235 | 276 | |||
Total assets | 15,355 | 15,355 | 15,206 | ||||
Pre-tax impairment charges | 36 | 0 | 155 | 0 | |||
SOUTHERN POWER CO | Wind Generating Facility | |||||||
Segment Reporting Information [Line Items] | |||||||
Pre-tax impairment charges | 36 | 155 | |||||
After tax impairment charges | 27 | 116 | |||||
SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 492 | 565 | 2,861 | 2,841 | |||
Segment net income (loss) | 46 | 15 | 294 | 303 | |||
Goodwill | 5,015 | 5,015 | 5,967 | ||||
Total assets | 20,398 | 20,398 | 22,987 | ||||
Net gain (loss) on dispositions | 353 | 0 | 317 | 0 | |||
Goodwill impairment | 0 | $ 42 | 0 | 42 | 0 | ||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | |||||||
Segment Reporting Information [Line Items] | |||||||
Number of natural gas distribution utilities disposed | utility | 3 | ||||||
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Pivotal Home Solutions | |||||||
Segment Reporting Information [Line Items] | |||||||
Net gain (loss) on dispositions | 353 | 317 | |||||
Net gain (loss) on dispositions, net of tax | 40 | (35) | |||||
Goodwill impairment | $ 42 | 42 | |||||
Electric Utilities | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 5,509 | 5,523 | 14,456 | 14,239 | |||
Segment net income (loss) | 1,240 | 1,132 | 1,946 | 276 | |||
Goodwill | 2 | 2 | 2 | ||||
Total assets | 90,102 | 90,102 | 87,085 | ||||
SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 492 | 565 | 2,861 | 2,841 | |||
Gas Distribution Operations | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Goodwill | 4,034 | 4,034 | 4,702 | ||||
Net gain (loss) on dispositions | 351 | 351 | |||||
Net gain (loss) on dispositions, net of tax | 38 | 38 | |||||
Goodwill impairment | 0 | ||||||
Gas Marketing Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Goodwill | 981 | 981 | 1,265 | ||||
Net gain (loss) on dispositions | 2 | (34) | |||||
Net gain (loss) on dispositions, net of tax | 2 | (73) | |||||
Goodwill impairment | 42 | ||||||
Operating Segments | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 497 | 607 | 2,902 | 3,000 | |||
Segment net income (loss) | 64 | 44 | 338 | 325 | |||
Total assets | 21,524 | 21,524 | 24,842 | ||||
Operating Segments | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 492 | 565 | 2,861 | 2,841 | |||
Segment net income (loss) | 46 | 15 | 294 | 303 | |||
Goodwill | 5,015 | 5,015 | 5,967 | ||||
Total assets | 20,398 | 20,398 | 22,987 | ||||
Operating Segments | Gas Distribution Operations | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 441 | 472 | 2,297 | 2,255 | |||
Segment net income (loss) | 74 | 52 | 290 | 223 | |||
Total assets | 16,850 | 16,850 | 19,358 | ||||
Revenue on disposition | $ 8 | 50 | |||||
Net income on disposition | $ 245 | 274 | |||||
Operating Segments | Gas Distribution Operations | SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | |||||||
Segment Reporting Information [Line Items] | |||||||
Number of natural gas distribution utilities disposed | utility | 3 | 3 | |||||
Operating Segments | Gas Marketing Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | $ 44 | 143 | $ 403 | 597 | |||
Segment net income (loss) | (8) | 1 | (71) | 36 | |||
Total assets | 1,522 | 1,522 | 2,147 | ||||
Revenue on disposition | 32 | ||||||
Net income on disposition | 55 | 95 | |||||
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | (8) | (24) | 142 | 95 | |||
Segment net income (loss) | (18) | (23) | 65 | 28 | |||
Total assets | 855 | 855 | 1,096 | ||||
Less Gross Gas Costs | 1,663 | 1,538 | 5,057 | 5,048 | |||
Operating Segments | Gas Midstream Operations | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 20 | 16 | 60 | 53 | |||
Segment net income (loss) | 16 | 14 | 54 | 38 | |||
Total assets | 2,297 | 2,297 | 2,241 | ||||
Operating Segments | All Other | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 202 | 153 | 984 | 442 | |||
Segment net income (loss) | (119) | (80) | (292) | (232) | |||
Goodwill | 298 | 298 | 299 | ||||
Total assets | 3,086 | 3,086 | 2,552 | ||||
Operating Segments | All Other | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 1 | 2 | 3 | 7 | |||
Segment net income (loss) | (18) | (29) | (44) | (22) | |||
Total assets | 10,146 | 10,146 | 12,184 | ||||
Operating Segments | Third Party Gross Revenues | Wholesale Gas Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 1,573 | 1,411 | 4,847 | 4,781 | |||
Operating Segments | Intercompany Revenues | Wholesale Gas Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 82 | 103 | 352 | 362 | |||
Operating Segments | Total Gross Revenues | Wholesale Gas Services | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 1,655 | 1,514 | 5,199 | 5,143 | |||
Eliminations | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | (44) | (40) | (143) | (119) | |||
Segment net income (loss) | (3) | 2 | 0 | 0 | |||
Goodwill | 0 | 0 | 0 | ||||
Total assets | (1,869) | (1,869) | (1,619) | ||||
Eliminations | SOUTHERN Co GAS | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | (6) | (44) | (44) | (166) | |||
Segment net income (loss) | 0 | 0 | 0 | 0 | |||
Total assets | (11,272) | (11,272) | (14,039) | ||||
Reportable Subsegments | Traditional Electric Operating Companies | Electric Utilities | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 5,014 | 5,017 | 13,117 | 12,960 | |||
Segment net income (loss) | 1,148 | 1,008 | 1,711 | 0 | |||
Goodwill | 0 | 0 | 0 | ||||
Total assets | 75,069 | 75,069 | 72,204 | ||||
Reportable Subsegments | SOUTHERN POWER CO | Electric Utilities | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | 635 | 618 | 1,699 | 1,597 | |||
Segment net income (loss) | 92 | 124 | 235 | 276 | |||
Goodwill | 2 | 2 | 2 | ||||
Total assets | 15,355 | 15,355 | 15,206 | ||||
Intersubsegment Eliminations | Electric Utilities | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating revenues | (140) | (112) | (360) | (318) | |||
Segment net income (loss) | 0 | $ 0 | 0 | $ 0 | |||
Goodwill | 0 | 0 | 0 | ||||
Total assets | $ (322) | $ (322) | $ (325) |
Segment and Related Informati_5
Segment and Related Information - Financial Data for Products and Services (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2018 | Sep. 30, 2017 | Sep. 30, 2018 | Sep. 30, 2017 | |
Revenue from External Customer [Line Items] | ||||
Total operating revenues | $ 6,159 | $ 6,201 | $ 18,158 | $ 17,403 |
Retail | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 4,605 | 4,615 | 11,913 | 11,786 |
Electric Utilities' Revenues | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 5,509 | 5,523 | 14,456 | 14,239 |
Electric Utilities' Revenues | Retail | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 4,605 | 4,615 | 11,913 | 11,786 |
Electric Utilities' Revenues | Wholesale | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 693 | 718 | 1,923 | 1,867 |
Electric Utilities' Revenues | Other | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 211 | 190 | 620 | 586 |
Southern Company Gas' Revenues | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 492 | 565 | 2,861 | 2,841 |
Southern Company Gas' Revenues | Gas Distribution Operations | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 438 | 430 | 2,276 | 2,119 |
Southern Company Gas' Revenues | Gas Marketing Services | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | 44 | 143 | 403 | 597 |
Southern Company Gas' Revenues | Other | ||||
Revenue from External Customer [Line Items] | ||||
Total operating revenues | $ 10 | $ (8) | $ 182 | $ 125 |