Document And Entity Information
Document And Entity Information - USD ($) | 12 Months Ended | ||
Dec. 31, 2015 | Jan. 29, 2016 | Jun. 30, 2015 | |
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Dec. 31, 2015 | ||
Document Fiscal Year Focus | 2,015 | ||
Document Fiscal Period Focus | FY | ||
Trading Symbol | AEE | ||
Entity Registrant Name | AMEREN CORP | ||
Entity Central Index Key | 1,002,910 | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Common Stock, Shares Outstanding | 242,634,798 | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Public Float | $ 9,142,479,189 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Union Electric Company | |||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Dec. 31, 2015 | ||
Document Fiscal Year Focus | 2,015 | ||
Document Fiscal Period Focus | FY | ||
Trading Symbol | AEE | ||
Entity Registrant Name | UNION ELECTRIC CO | ||
Entity Central Index Key | 100,826 | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock, Shares Outstanding | 102,123,834 | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Well-known Seasoned Issuer | No | ||
Ameren Illinois Company | |||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Dec. 31, 2015 | ||
Document Fiscal Year Focus | 2,015 | ||
Document Fiscal Period Focus | FY | ||
Trading Symbol | AEE | ||
Entity Registrant Name | Ameren Illinois Co | ||
Entity Central Index Key | 18,654 | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock, Shares Outstanding | 25,452,373 | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Well-known Seasoned Issuer | Yes |
Consolidated Statement Of Incom
Consolidated Statement Of Income (Loss) - USD ($) shares in Millions, $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Operating Revenues: | ||||
Electric | $ 5,180 | $ 4,913 | $ 4,832 | |
Gas | 918 | 1,140 | 1,006 | |
Total operating revenues | 6,098 | 6,053 | 5,838 | |
Operating Expenses: | ||||
Fuel | 878 | 826 | 845 | |
Purchased power | 514 | 461 | 508 | |
Gas purchased for resale | 415 | 615 | 526 | |
Other operations and maintenance | 1,694 | 1,684 | 1,611 | |
Provision for Callaway construction and operating license | 69 | 0 | ||
Depreciation and amortization | 796 | 745 | 706 | |
Taxes other than income taxes | 473 | 468 | 458 | |
Total operating expenses | 4,839 | 4,799 | 4,654 | |
Operating Income | 1,259 | 1,254 | 1,184 | |
Other Income and Expenses: | ||||
Miscellaneous income | [1] | 74 | 79 | 69 |
Miscellaneous expense | [1] | 30 | 22 | 26 |
Total other income (expense) | 44 | 57 | 43 | |
Interest charges | 355 | 341 | 398 | |
Income Before Income Taxes | 948 | 970 | 829 | |
Income taxes | 363 | 377 | 311 | |
Income from Continuing Operations | 585 | 593 | 518 | |
Income (Loss) from Discontinued Operations, Net of Tax (Note 16) | 51 | (1) | (223) | |
Net Income (Loss) | 636 | 592 | 295 | |
Pension and other postretirement activity, net of income taxes (benefit) | 6 | (12) | 30 | |
Comprehensive Income (Loss) | 636 | 574 | 300 | |
Less: Net Income (Loss) Attributable to Noncontrolling Interests: | ||||
Continuing Operations | 6 | 6 | 6 | |
Net Income (Loss): | ||||
Net income attributable to Ameren Corporation - continuing operations | 579 | 587 | 512 | |
Discontinued Operations | 51 | (1) | (223) | |
Net income (loss) attributable to Ameren Corporation | $ 630 | $ 586 | $ 289 | |
Earnings (Loss) per Common Share – Basic: | ||||
Continuing Operations - Basic | $ 2.39 | $ 2.42 | $ 2.11 | |
Discontinued Operations - Basic | 0.21 | 0 | (0.92) | |
Earnings (Loss) per Common Share – Basic | 2.60 | 2.42 | 1.19 | |
Earnings (Loss) per Common Share – Diluted: | ||||
Continuing Operations - Diluted | 2.38 | 2.40 | 2.10 | |
Discontinued Operations - Diluted | 0.21 | 0 | (0.92) | |
Earnings (Loss) per Common Share – Diluted | 2.59 | 2.40 | 1.18 | |
Dividends per Common Share | $ 1.655 | $ 1.61 | $ 1.6 | |
Average Common Shares Outstanding - Basic | 242.6 | 242.6 | 242.6 | |
Average Common Shares Outstanding - Diluted | 243.6 | 244.4 | 244.5 | |
Union Electric Company | ||||
Operating Revenues: | ||||
Electric | $ 3,470 | $ 3,388 | $ 3,379 | |
Gas | 137 | 164 | 161 | |
Other | 2 | 1 | 1 | |
Total operating revenues | 3,609 | 3,553 | 3,541 | |
Operating Expenses: | ||||
Fuel | 878 | 826 | 845 | |
Purchased power | 111 | 126 | 133 | |
Gas purchased for resale | 57 | 82 | 78 | |
Other operations and maintenance | 925 | 939 | 909 | |
Provision for Callaway construction and operating license | 69 | 0 | 0 | |
Depreciation and amortization | 492 | 473 | 454 | |
Taxes other than income taxes | 335 | 322 | 319 | |
Total operating expenses | 2,867 | 2,768 | 2,738 | |
Operating Income | 742 | 785 | 803 | |
Other Income and Expenses: | ||||
Miscellaneous income | 52 | 60 | 58 | |
Miscellaneous expense | 11 | 12 | 11 | |
Total other income (expense) | 41 | 48 | 47 | |
Interest charges | 219 | 211 | 210 | |
Income Before Income Taxes | 564 | 622 | 640 | |
Income taxes | 209 | 229 | 242 | |
Net Income (Loss) | 355 | 393 | 398 | |
Other Comprehensive Income | 0 | 0 | 0 | |
Comprehensive Income (Loss) | 355 | 393 | 398 | |
Net Income (Loss): | ||||
Net income (loss) attributable to Ameren Corporation | 355 | 393 | 398 | |
Preferred Stock Dividends | 3 | 3 | 3 | |
Net Income Available to Common Stockholder | 352 | 390 | 395 | |
Ameren Illinois Company | ||||
Operating Revenues: | ||||
Electric | 1,683 | 1,522 | 1,461 | |
Gas | 783 | 976 | 847 | |
Other | 3 | |||
Total operating revenues | 2,466 | 2,498 | 2,311 | |
Operating Expenses: | ||||
Purchased power | 420 | 343 | 380 | |
Gas purchased for resale | 358 | 533 | 448 | |
Other operations and maintenance | 797 | 771 | 693 | |
Depreciation and amortization | 295 | 263 | 243 | |
Taxes other than income taxes | 130 | 138 | 132 | |
Total operating expenses | 2,000 | 2,048 | 1,896 | |
Operating Income | 466 | 450 | 415 | |
Other Income and Expenses: | ||||
Miscellaneous income | 21 | 17 | 10 | |
Miscellaneous expense | 12 | 8 | 9 | |
Total other income (expense) | 9 | 9 | 1 | |
Interest charges | 131 | 112 | 143 | |
Income Before Income Taxes | 344 | 347 | 273 | |
Income taxes | 127 | 143 | 110 | |
Net Income (Loss) | 217 | 204 | 163 | |
Pension and other postretirement activity, net of income taxes (benefit) | (3) | (3) | (3) | |
Comprehensive Income (Loss) | 214 | 201 | 160 | |
Net Income (Loss): | ||||
Net income (loss) attributable to Ameren Corporation | 217 | 204 | 163 | |
Preferred Stock Dividends | 3 | 3 | 3 | |
Net Income Available to Common Stockholder | $ 214 | $ 201 | $ 160 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Consolidated Statement Of Inco3
Consolidated Statement Of Income (Loss) (Parenthetical) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Pension and other postretirement activity, tax (benefit) | $ 3 | $ (7) | $ 16 |
Ameren Illinois Company | |||
Pension and other postretirement activity, tax (benefit) | $ (2) | $ (2) | $ (2) |
Consolidated Statement Of Compr
Consolidated Statement Of Comprehensive Income - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Income from Continuing Operations | $ 585 | $ 593 | $ 518 |
Pension and other postretirement activity, net of income taxes (benefit) | 6 | (12) | 30 |
Comprehensive Income (Loss) from Continuing Operations | 591 | 581 | 548 |
Less: Comprehensive Income from Continuing Operations Attributable to Noncontrolling Interests | 6 | 6 | 6 |
Comprehensive Income from Continuing Operations Attributable to Ameren Corporation | 585 | 575 | 542 |
Income (Loss) from Discontinued Operations, Net of Tax (Note 16) | 51 | (1) | (223) |
Comprehensive Income from Continuing Operations Attributable to Ameren Corporation | 0 | (18) | |
Comprehensive Income (Loss) from Discontinued Operations | 51 | (1) | (241) |
Less: Comprehensive Income from Discontinuing Operations Attributable to Noncontrolling Interest | 0 | 1 | |
Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Corporation | 51 | (1) | (242) |
Comprehensive Income (Loss) | 636 | 574 | 300 |
Ameren Illinois Company | |||
Pension and other postretirement activity, net of income taxes (benefit) | (3) | (3) | (3) |
Comprehensive Income (Loss) | $ 214 | $ 201 | $ 160 |
Consolidated Statement Of Comp5
Consolidated Statement Of Comprehensive Income (Parenthetical) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Pension and other postretirement activity, tax (benefit) | $ 3 | $ (7) | $ 16 |
Other Comprehensive Income (Loss) from Discontinued Operations Tax (Benefit) | $ 0 | $ 0 | $ (10) |
Consolidated Balance Sheet
Consolidated Balance Sheet - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Current Assets: | |||
Cash and cash equivalents | $ 292 | $ 5 | |
Accounts receivable - trade (less allowance for doubtful accounts) | 388 | 423 | |
Unbilled revenue | 239 | 265 | |
Miscellaneous accounts and notes receivable | 98 | 81 | |
Materials and supplies | 538 | 524 | |
Current regulatory assets | 260 | 295 | |
Other current assets | 88 | 86 | |
Assets of discontinued operations (Note 16) | 14 | 15 | |
Total current assets | 1,917 | 1,694 | |
Property, Plant and Equipment, Net | [1] | 18,799 | 17,424 |
Investments and Other Assets: | |||
Nuclear decommissioning trust fund | 556 | 549 | |
Goodwill | 411 | 411 | |
Regulatory assets | 1,382 | 1,582 | |
Other assets | 575 | 629 | |
Total investments and other assets | 2,924 | 3,171 | |
TOTAL ASSETS | 23,640 | 22,289 | |
Current Liabilities: | |||
Current maturities of long-term debt | 395 | 120 | |
Short-term debt | 301 | 714 | |
Accounts and wages payable | 777 | 711 | |
Taxes accrued | 43 | 46 | |
Interest accrued | 89 | 85 | |
Current regulatory liabilities | 80 | 106 | |
Other current liabilities | 379 | 434 | |
Liabilities of discontinued operations (Note 16) | 29 | 33 | |
Total current liabilities | 2,093 | 2,249 | |
Long-term Debt, Net | 6,880 | 6,085 | |
Deferred Credits and Other Liabilities: | |||
Accumulated deferred income taxes, net | 3,885 | 3,571 | |
Accumulated deferred investment tax credits | 60 | 64 | |
Regulatory liabilities | 1,905 | 1,850 | |
Asset retirement obligations | 618 | 396 | |
Pension and other postretirement benefits | 580 | 705 | |
Other deferred credits and liabilities | 531 | 514 | |
Total deferred credits and other liabilities | $ 7,579 | $ 7,100 | |
Commitments and Contingencies (Notes 2, 10, 14 and 15) | |||
Stockholders' Equity: | |||
Common stock | $ 2 | $ 2 | |
Other paid-in capital, principally premium on common stock | 5,616 | 5,617 | |
Retained earnings | 1,331 | 1,103 | |
Accumulated other comprehensive income (loss) | (3) | (9) | |
Total stockholders' equity | 6,946 | 6,713 | |
Noncontrolling Interests | 142 | 142 | |
Total equity | 7,088 | 6,855 | |
TOTAL LIABILITIES AND EQUITY | 23,640 | 22,289 | |
Union Electric Company | |||
Current Assets: | |||
Cash and cash equivalents | 199 | 1 | |
Advances to money pool | 36 | 0 | |
Accounts receivable - trade (less allowance for doubtful accounts) | 174 | 190 | |
Accounts receivable - affiliates | 54 | 65 | |
Unbilled revenue | 128 | 146 | |
Miscellaneous accounts and notes receivable | 78 | 35 | |
Materials and supplies | 387 | 347 | |
Current regulatory assets | 89 | 163 | |
Other current assets | 41 | 43 | |
Total current assets | 1,186 | 990 | |
Property, Plant and Equipment, Net | [1] | 11,183 | 10,867 |
Investments and Other Assets: | |||
Nuclear decommissioning trust fund | 556 | 549 | |
Regulatory assets | 605 | 695 | |
Other assets | 321 | 373 | |
Total investments and other assets | 1,482 | 1,617 | |
TOTAL ASSETS | 13,851 | 13,474 | |
Current Liabilities: | |||
Current maturities of long-term debt | 266 | 120 | |
Short-term debt | 0 | 97 | |
Accounts and wages payable | 417 | 405 | |
Accounts payable - affiliates | 56 | 56 | |
Taxes accrued | 31 | 32 | |
Interest accrued | 59 | 58 | |
Current regulatory liabilities | 28 | 18 | |
Other current liabilities | 120 | 117 | |
Total current liabilities | 977 | 903 | |
Long-term Debt, Net | 3,844 | 3,861 | |
Deferred Credits and Other Liabilities: | |||
Accumulated deferred income taxes, net | 2,844 | 2,757 | |
Accumulated deferred investment tax credits | 58 | 61 | |
Regulatory liabilities | 1,172 | 1,147 | |
Asset retirement obligations | 612 | 389 | |
Pension and other postretirement benefits | 234 | 274 | |
Other deferred credits and liabilities | 28 | 30 | |
Total deferred credits and other liabilities | $ 4,948 | $ 4,658 | |
Commitments and Contingencies (Notes 2, 10, 14 and 15) | |||
Stockholders' Equity: | |||
Common stock | $ 511 | $ 511 | |
Other paid-in capital, principally premium on common stock | 1,822 | 1,569 | |
Preferred stock not subject to mandatory redemption | 80 | 80 | |
Retained earnings | 1,669 | 1,892 | |
Total stockholders' equity | 4,082 | 4,052 | |
TOTAL LIABILITIES AND EQUITY | 13,851 | 13,474 | |
Ameren Illinois Company | |||
Current Assets: | |||
Cash and cash equivalents | 71 | 1 | |
Accounts receivable - trade (less allowance for doubtful accounts) | 204 | 212 | |
Accounts receivable - affiliates | 22 | 22 | |
Unbilled revenue | 111 | 119 | |
Miscellaneous accounts and notes receivable | 19 | 9 | |
Materials and supplies | 151 | 177 | |
Current regulatory assets | 167 | 129 | |
Other current assets | 15 | 15 | |
Total current assets | 760 | 684 | |
Property, Plant and Equipment, Net | 6,848 | 6,165 | |
Investments and Other Assets: | |||
Goodwill | 411 | 411 | |
Regulatory assets | 771 | 883 | |
Other assets | 113 | 61 | |
Total investments and other assets | 1,295 | 1,355 | |
TOTAL ASSETS | 8,903 | 8,204 | |
Current Liabilities: | |||
Current maturities of long-term debt | 129 | 0 | |
Short-term debt | 0 | 32 | |
Borrowings from money pool | 0 | 15 | |
Accounts and wages payable | 249 | 207 | |
Accounts payable - affiliates | 66 | 50 | |
Taxes accrued | 13 | 17 | |
Customer deposits | 69 | 77 | |
Mark-to-market derivative liabilities | 45 | 42 | |
Environmental remediation | 28 | 52 | |
Current regulatory liabilities | 39 | 84 | |
Other current liabilities | 114 | 124 | |
Total current liabilities | 752 | 700 | |
Long-term Debt, Net | 2,342 | 2,224 | |
Deferred Credits and Other Liabilities: | |||
Accumulated deferred income taxes, net | 1,480 | 1,248 | |
Accumulated deferred investment tax credits | 2 | 3 | |
Regulatory liabilities | 732 | 703 | |
Pension and other postretirement benefits | 271 | 277 | |
Accrued Environmental Loss Contingencies, Noncurrent | 205 | 199 | |
Other deferred credits and liabilities | 222 | 189 | |
Total deferred credits and other liabilities | $ 2,912 | $ 2,619 | |
Commitments and Contingencies (Notes 2, 10, 14 and 15) | |||
Stockholders' Equity: | |||
Common stock | $ 0 | $ 0 | |
Other paid-in capital, principally premium on common stock | 2,005 | 1,980 | |
Preferred stock not subject to mandatory redemption | 62 | 62 | |
Retained earnings | 825 | 611 | |
Accumulated other comprehensive income (loss) | 5 | 8 | |
Total stockholders' equity | 2,897 | 2,661 | |
TOTAL LIABILITIES AND EQUITY | $ 8,903 | $ 8,204 | |
[1] | (a)Amounts in Ameren and Ameren Missouri include two CTs under separate capital lease agreements. The gross cumulative asset value of those agreements was $233 million at December 31, 2015 and 2014. The total accumulated depreciation associated with the two CTs was $72 million and $66 million at December 31, 2015 and 2014, respectively. In addition, Ameren Missouri has investments in debt securities, which were classified as held-to-maturity and recorded in "Other assets", related to the two CTs from the city of Bowling Green and Audrain County. As of December 31, 2015 and 2014, the carrying value of these debt securities was $288 million and $294 million, respectively. |
Consolidated Balance Sheet (Par
Consolidated Balance Sheet (Parenthetical) - USD ($) shares in Millions, $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 |
Accounts receivable - trade, allowance for doubtful accounts | $ 19 | $ 21 |
Common stock, par value | $ 0.01 | $ 0.01 |
Common stock, shares authorized | 400 | 400 |
Common stock, shares outstanding | 242.6 | 242.6 |
Union Electric Company | ||
Accounts receivable - trade, allowance for doubtful accounts | $ 7 | $ 8 |
Common stock, par value | $ 5 | $ 5 |
Common stock, shares authorized | 150 | 150 |
Common stock, shares outstanding | 102.1 | 102.1 |
Ameren Illinois Company | ||
Accounts receivable - trade, allowance for doubtful accounts | $ 12 | $ 13 |
Common Stock, No Par Value | $ 0 | $ 0 |
Common stock, shares authorized | 45 | 45 |
Common stock, shares outstanding | 25.5 | 25.5 |
Consolidated Statement Of Cash
Consolidated Statement Of Cash Flows - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Cash Flows From Operating Activities: | ||||
Net income (loss) | $ 636 | $ 592 | $ 295 | |
(Income) Loss from discontinued operations, net of tax | (51) | 1 | 223 | |
Adjustments to reconcile net income to net cash provided by operating activities: | ||||
Provision for Callaway construction and operating license | 69 | 0 | ||
Depreciation and amortization | 777 | 710 | 666 | |
Amortization of nuclear fuel | 97 | 81 | 71 | |
Amortization of debt issuance costs and premium/discounts | 22 | 22 | 24 | |
Deferred income taxes and investment tax credits, net | 369 | 451 | 410 | |
Allowance for equity funds used during construction | [1] | (30) | (34) | (37) |
Share-based Compensation | 24 | 25 | 27 | |
Other | (10) | (24) | 23 | |
Changes in assets and liabilities: | ||||
Receivables | 83 | 31 | (60) | |
Materials and supplies | (14) | 3 | 60 | |
Accounts and wages payable | (2) | 10 | 81 | |
Taxes accrued | (24) | (44) | (195) | |
Regulatory assets and liabilities | 94 | (281) | 29 | |
Assets, other | 53 | 30 | 20 | |
Liabilities, other | (56) | (28) | (14) | |
Pension and other postretirement benefits | (9) | (10) | (28) | |
Counterparty collateral, net | (7) | 22 | 41 | |
Net cash provided by operating activities - continuing operations | 2,021 | 1,557 | 1,636 | |
Net cash provided by operating activities - discontinued operations | (4) | (6) | 57 | |
Net cash provided by operating activities | 2,017 | 1,551 | 1,693 | |
Cash Flows From Investing Activities: | ||||
Capital expenditures | (1,917) | (1,785) | (1,379) | |
Nuclear fuel expenditures | (52) | (74) | (45) | |
Purchases of securities - nuclear decommissioning trust fund | (363) | (405) | (214) | |
Sales and maturities of securities - nuclear decommissioning trust fund | 349 | 391 | 196 | |
Proceeds from Collection of Notes Receivable | 20 | 95 | 6 | |
Contributions to Note Receivable | (8) | (89) | (5) | |
Other | 20 | 11 | 1 | |
Net cash used in investing activities - continuing operations | (1,951) | (1,856) | (1,440) | |
Net cash used in investing activities - discontinued operations | (25) | 139 | (283) | |
Net cash used in investing activities | (1,976) | (1,717) | (1,723) | |
Cash Flows From Financing Activities: | ||||
Dividends on common stock | (402) | (390) | (388) | |
Dividends paid to noncontrolling interest holders | (6) | (6) | (6) | |
Short-term debt, net | (413) | 346 | 368 | |
Maturities, redemptions, and repurchases of long-term debt | (120) | (697) | (399) | |
Issuances of Long-term debt | 1,197 | 898 | 278 | |
Capital issuance costs | (12) | (11) | (2) | |
Other | 2 | 1 | 0 | |
Net cash provided by (used in) financing activities | 246 | 141 | (149) | |
Net change in cash and cash equivalents | 287 | (25) | (179) | |
Cash and cash equivalents at beginning of year | 5 | 30 | 209 | |
Cash and cash equivalents at end of year | 292 | 5 | 30 | |
Cash Paid (Refunded) During the Year: | ||||
Interest net of capitalized | 335 | 333 | 393 | |
Income taxes, net | (15) | (27) | 8 | |
Union Electric Company | ||||
Cash Flows From Operating Activities: | ||||
Net income (loss) | 355 | 393 | 398 | |
Adjustments to reconcile net income to net cash provided by operating activities: | ||||
Provision for Callaway construction and operating license | 69 | 0 | 0 | |
Depreciation and amortization | 476 | 442 | 419 | |
Amortization of nuclear fuel | 97 | 81 | 71 | |
FAC prudence review charge | 26 | |||
Amortization of debt issuance costs and premium/discounts | 6 | 7 | 7 | |
Deferred income taxes and investment tax credits, net | 82 | 245 | 65 | |
Allowance for equity funds used during construction | (22) | (32) | (31) | |
Other | 2 | 3 | 1 | |
Changes in assets and liabilities: | ||||
Receivables | 72 | (10) | (59) | |
Materials and supplies | (39) | 8 | 45 | |
Accounts and wages payable | 3 | 25 | 42 | |
Taxes accrued | 1 | (197) | 100 | |
Regulatory assets and liabilities | 117 | (68) | 68 | |
Assets, other | 26 | 52 | 18 | |
Liabilities, other | 4 | 0 | (29) | |
Pension and other postretirement benefits | (2) | 1 | 2 | |
Net cash provided by operating activities | 1,247 | 950 | 1,143 | |
Cash Flows From Investing Activities: | ||||
Capital expenditures | (622) | (747) | (648) | |
Nuclear fuel expenditures | (52) | (74) | (45) | |
Purchases of securities - nuclear decommissioning trust fund | (363) | (405) | (214) | |
Sales and maturities of securities - nuclear decommissioning trust fund | 349 | 391 | 196 | |
Money pool advances, net | 36 | (24) | ||
Other | (2) | 0 | ||
Net cash used in investing activities | (724) | (837) | (687) | |
Cash Flows From Financing Activities: | ||||
Dividends on common stock | (575) | (340) | (460) | |
Return of capital to parent | 0 | (215) | ||
Dividends on preferred stock | (3) | (3) | (3) | |
Money pool borrowings, net | 0 | (105) | 105 | |
Short-term debt, net | (97) | 97 | ||
Maturities, redemptions, and repurchases of long-term debt | (120) | (109) | (249) | |
Issuances of Long-term debt | 249 | 350 | ||
Capital issuance costs | (3) | (3) | ||
Capital contribution from parent | 224 | 215 | 4 | |
Net cash provided by (used in) financing activities | (325) | (113) | (603) | |
Net change in cash and cash equivalents | 198 | 0 | (147) | |
Cash and cash equivalents at beginning of year | 1 | 1 | 148 | |
Cash and cash equivalents at end of year | 199 | 1 | 1 | |
Noncash Or Part Noncash Capital Contribution From Parent | 38 | 9 | 0 | |
Cash Paid (Refunded) During the Year: | ||||
Interest net of capitalized | 212 | 203 | 212 | |
Income taxes, net | 72 | 215 | 86 | |
Ameren Illinois Company | ||||
Cash Flows From Operating Activities: | ||||
Net income (loss) | 217 | 204 | 163 | |
Adjustments to reconcile net income to net cash provided by operating activities: | ||||
Depreciation and amortization | 292 | 259 | 238 | |
Amortization of debt issuance costs and premium/discounts | 14 | 13 | 15 | |
Deferred income taxes and investment tax credits, net | 221 | 196 | 104 | |
Allowance for equity funds used during construction | (8) | (2) | (6) | |
Other | (14) | (19) | 4 | |
Changes in assets and liabilities: | ||||
Receivables | 16 | (13) | 50 | |
Materials and supplies | 25 | (4) | 15 | |
Accounts and wages payable | 37 | 7 | 19 | |
Taxes accrued | (2) | (7) | 28 | |
Regulatory assets and liabilities | (26) | (215) | (35) | |
Assets, other | 17 | 15 | 5 | |
Liabilities, other | (27) | 1 | 10 | |
Pension and other postretirement benefits | (4) | (6) | (8) | |
Counterparty collateral, net | (3) | 14 | 43 | |
Net cash provided by operating activities | 763 | 445 | 651 | |
Cash Flows From Investing Activities: | ||||
Capital expenditures | (918) | (835) | (701) | |
Other | 5 | 7 | 6 | |
Net cash used in investing activities | (913) | (828) | (695) | |
Cash Flows From Financing Activities: | ||||
Dividends on common stock | 0 | (110) | ||
Dividends on preferred stock | (3) | (3) | (3) | |
Money pool borrowings, net | (15) | (41) | 32 | |
Short-term debt, net | (32) | 32 | ||
Maturities, redemptions, and repurchases of long-term debt | 0 | (163) | (150) | |
Issuances of Long-term debt | 248 | 548 | 278 | |
Capital issuance costs | (3) | (6) | (2) | |
Capital contribution from parent | 25 | 15 | ||
Other | 1 | 0 | ||
Net cash provided by (used in) financing activities | 220 | 383 | 45 | |
Net change in cash and cash equivalents | 70 | 0 | 1 | |
Cash and cash equivalents at beginning of year | 1 | 1 | 0 | |
Cash and cash equivalents at end of year | 71 | 1 | 1 | |
Cash Paid (Refunded) During the Year: | ||||
Interest net of capitalized | 120 | 110 | 112 | |
Income taxes, net | $ (113) | $ (44) | $ (23) | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Consolidated Statement Of Cash9
Consolidated Statement Of Cash Flows (Parenthetical) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Capitalized interest | $ 17 | $ 18 | $ 37 |
Union Electric Company | |||
Capitalized interest | 12 | 16 | 16 |
Ameren Illinois Company | |||
Capitalized interest | $ 5 | $ 2 | $ 4 |
Consolidated Statement Of Stock
Consolidated Statement Of Stockholders' Equity - USD ($) shares in Millions, $ in Millions | Total | Common Stock | Other Paid-In Capital | Retained Earnings | Derivative Financial Instruments | Deferred Retirement Benefit Costs | Accumulated Other Comprehensive Income (Loss) | Noncontrolling Interest | Total Ameren Corporation Stockholders' Equity | Union Electric Company | Union Electric CompanyCommon Stock | Union Electric CompanyOther Paid-In Capital | Union Electric CompanyPreferred Stock Not Subject To Mandatory Redemption | Union Electric CompanyRetained Earnings | Ameren Illinois Company | Ameren Illinois CompanyCommon Stock | Ameren Illinois CompanyOther Paid-In Capital | Ameren Illinois CompanyPreferred Stock Not Subject To Mandatory Redemption | Ameren Illinois CompanyRetained Earnings | Ameren Illinois CompanyDeferred Retirement Benefit Costs | Ameren Illinois CompanyAccumulated Other Comprehensive Income (Loss) |
Beginning of year at Dec. 31, 2012 | $ 2 | $ 5,616 | $ 1,006 | $ 25 | $ (33) | $ 151 | $ 1,556 | $ 1,907 | $ 1,965 | $ 360 | $ 14 | ||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||
Stock-based compensation activity | 16 | ||||||||||||||||||||
Net income (loss) attributable to Ameren Corporation | $ 289 | 289 | $ 398 | $ 163 | |||||||||||||||||
Net income (loss) | 295 | 398 | 398 | 163 | 163 | ||||||||||||||||
Common stock dividends | (388) | (460) | (110) | ||||||||||||||||||
Capital contribution from parent | 4 | 4 | 0 | ||||||||||||||||||
Preferred stock dividends | (3) | (3) | |||||||||||||||||||
Change in derivative financial instruments | (21) | ||||||||||||||||||||
Divestiture of derivative financial instruments | (4) | ||||||||||||||||||||
Change in deferred retirement benefit costs | $ (30) | 29 | 3 | $ (3) | |||||||||||||||||
Divestiture of deferred retirement benefit costs | 7 | ||||||||||||||||||||
Net income attributable to noncontrolling interest holder | 6 | ||||||||||||||||||||
Dividends paid to noncontrolling interest holders | (6) | ||||||||||||||||||||
Divestiture of noncontrolling interest | (9) | ||||||||||||||||||||
End of year (shares) at Dec. 31, 2013 | 242.6 | ||||||||||||||||||||
End of year at Dec. 31, 2013 | $ 6,686 | 2 | 5,632 | 907 | 0 | 3 | $ 3 | 142 | $ 511 | 1,560 | $ 80 | 1,842 | $ 0 | 1,965 | $ 62 | 410 | 11 | 11 | |||
Stockholders' equity, end of year at Dec. 31, 2013 | $ 6,544 | 3,993 | 2,448 | ||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||
Return of capital to parent | 0 | ||||||||||||||||||||
Stock-based compensation activity | (15) | ||||||||||||||||||||
Net income (loss) attributable to Ameren Corporation | 586 | 586 | 393 | 204 | |||||||||||||||||
Net income (loss) | 592 | 393 | 393 | 204 | 204 | ||||||||||||||||
Common stock dividends | (390) | (340) | 0 | ||||||||||||||||||
Capital contribution from parent | $ 215 | 224 | 15 | 15 | |||||||||||||||||
Preferred stock dividends | (3) | (3) | |||||||||||||||||||
Change in derivative financial instruments | 0 | ||||||||||||||||||||
Divestiture of derivative financial instruments | 0 | ||||||||||||||||||||
Change in deferred retirement benefit costs | $ 12 | (12) | $ 3 | (3) | |||||||||||||||||
Divestiture of deferred retirement benefit costs | 0 | ||||||||||||||||||||
Net income attributable to noncontrolling interest holder | 6 | ||||||||||||||||||||
Dividends paid to noncontrolling interest holders | (6) | ||||||||||||||||||||
Divestiture of noncontrolling interest | 0 | ||||||||||||||||||||
End of year (shares) at Dec. 31, 2014 | 242.6 | 102.1 | 25.5 | ||||||||||||||||||
End of year at Dec. 31, 2014 | $ 6,855 | 2 | 5,617 | 1,103 | 0 | (9) | (9) | 142 | 511 | 1,569 | 80 | 1,892 | 0 | 1,980 | 62 | 611 | 8 | 8 | |||
Stockholders' equity, end of year at Dec. 31, 2014 | 6,713 | 6,713 | $ 4,052 | $ 2,661 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||
Return of capital to parent | 215 | (215) | |||||||||||||||||||
Stock-based compensation activity | (1) | ||||||||||||||||||||
Net income (loss) attributable to Ameren Corporation | 630 | 630 | 355 | 217 | |||||||||||||||||
Net income (loss) | 636 | 355 | 355 | 217 | 217 | ||||||||||||||||
Common stock dividends | (402) | (575) | 0 | ||||||||||||||||||
Capital contribution from parent | $ 224 | 253 | 25 | 25 | |||||||||||||||||
Preferred stock dividends | (3) | (3) | |||||||||||||||||||
Change in derivative financial instruments | 0 | ||||||||||||||||||||
Divestiture of derivative financial instruments | 0 | ||||||||||||||||||||
Change in deferred retirement benefit costs | $ (6) | 6 | $ 3 | (3) | |||||||||||||||||
Divestiture of deferred retirement benefit costs | 0 | ||||||||||||||||||||
Net income attributable to noncontrolling interest holder | 6 | ||||||||||||||||||||
Dividends paid to noncontrolling interest holders | (6) | ||||||||||||||||||||
Divestiture of noncontrolling interest | 0 | ||||||||||||||||||||
End of year (shares) at Dec. 31, 2015 | 242.6 | 102.1 | 25.5 | ||||||||||||||||||
End of year at Dec. 31, 2015 | $ 7,088 | $ 2 | $ 5,616 | $ 1,331 | $ 0 | $ (3) | $ (3) | $ 142 | $ 511 | 1,822 | $ 80 | $ 1,669 | $ 0 | $ 2,005 | $ 62 | $ 825 | $ 5 | $ 5 | |||
Stockholders' equity, end of year at Dec. 31, 2015 | $ 6,946 | $ 6,946 | $ 4,082 | $ 2,897 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||
Return of capital to parent | $ 0 | $ 0 |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2015 | |
Accounting Policies [Abstract] | |
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES General Ameren, headquartered in St. Louis, Missouri, is a public utility holding company under PUHCA 2005. Ameren’s primary assets are its equity interests in its subsidiaries, including Ameren Missouri and Ameren Illinois. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. • Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas transmission and distribution business in Missouri. Ameren Missouri was incorporated in Missouri in 1922 and is successor to a number of companies, the oldest of which was organized in 1881. It is the largest electric utility in the state of Missouri. It supplies electric and natural gas service to a 24,000 -square-mile area in central and eastern Missouri. This area has an estimated population of 2.8 million and includes the Greater St. Louis area. Ameren Missouri supplies electric service to 1.2 million customers and natural gas service to 0.1 million customers. • Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric and natural gas transmission and distribution businesses in Illinois. Ameren Illinois was created by the merger of CILCO and IP with and into CIPS in 2010. CIPS was incorporated in Illinois in 1923 and was the successor to a number of companies, the oldest of which was organized in 1902. Ameren Illinois supplies electric and natural gas utility service to portions of central and southern Illinois having an estimated population of 3.1 million in an area of 40,000 square miles. Ameren Illinois supplies electric service to 1.2 million customers and natural gas service to 0.8 million customers. Ameren has various other subsidiaries that conduct activities such as the provision of shared services. Ameren also has a subsidiary, ATXI, that operates a FERC rate-regulated electric transmission business. ATXI is developing MISO-approved electric transmission projects, including the Illinois Rivers, Spoon River, and Mark Twain projects. Ameren is also pursuing projects to improve electric transmission system reliability within Ameren Missouri's and Ameren Illinois' service territories as well as competitive electric transmission investment opportunities outside of these territories, including investments outside of MISO. In December 2013, Ameren completed the divestiture of New AER to IPH. In January 2014, Medina Valley completed its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital. In addition, in 2013, Ameren abandoned the Meredosia and Hutsonville energy centers upon the completion of the divestiture of New AER to IPH. Ameren is demolishing the Hutsonville energy center and expects to demolish the Meredosia energy center beginning in 2016. As a result of these events, Ameren has segregated New AER’s and the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers’ operating results, assets, and liabilities and presented them separately as discontinued operations for all periods presented in this report. Unless otherwise stated, these notes to the financial statements exclude discontinued operations for all periods presented. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information regarding these transactions. Ameren's financial statements are prepared on a consolidated basis, and therefore include the accounts of its majority-owned subsidiaries. Ameren Missouri and Ameren Illinois have no subsidiaries and therefore their financial statements are not prepared on a consolidated basis. All intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated. Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the reported periods. Actual results could differ from those estimates. Regulation We are regulated by the MoPSC, the ICC, and the FERC. We defer certain costs as assets pursuant to actions of rate regulators or because of expectations that we will be able to recover such costs in future rates charged to customers. We also defer certain amounts as liabilities pursuant to actions of rate regulators or based on the expectation that such amounts will be returned to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. In addition to the cost recovery mechanisms discussed in the Purchased Gas, Power, and Fuel Rate-adjustment Mechanisms section below, Ameren Missouri and Ameren Illinois have approvals from rate regulators to use other cost recovery mechanisms. Ameren Missouri has a pension and postretirement benefit cost tracker, an uncertain tax positions tracker, a renewable energy standards cost tracker, a solar rebate program tracker, and the MEEIA energy efficiency rider. Ameren Illinois' and ATXI's electric transmission rates are determined pursuant to formula ratemaking. Additionally, Ameren Illinois' electric distribution business participates in the performance-based formula ratemaking process established pursuant to the IEIMA. Ameren Illinois also has an environmental cost rider, an asbestos-related litigation rider, an energy efficiency rider, a QIP rider, a VBA rider, and a bad debt rider. See Note 2 – Rate and Regulatory Matters for additional information on regulatory assets and liabilities. Cash and Cash Equivalents Cash and cash equivalents include cash on hand and temporary investments purchased with an original maturity of three months or less. Allowance for Doubtful Accounts Receivable The allowance for doubtful accounts represents our estimate of existing accounts receivable that will ultimately be uncollectible. The allowance is calculated by applying estimated loss factors to various classes of outstanding receivables, including unbilled revenue. The loss factors used to estimate uncollectible accounts are based upon both historical collections experience and management’s estimate of future collections success given the existing and anticipated future collections environment. Ameren Illinois has a bad debt rider that adjusts rates for net write-offs of customer accounts receivable above or below those being collected in rates. Materials and Supplies Materials and supplies are recorded at the lower of cost or market. Cost is determined by the average-cost method. Materials and supplies are capitalized as inventory when purchased and then expensed or capitalized as plant assets when installed, as appropriate. The following table presents a breakdown of materials and supplies for each of the Ameren Companies at December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Ameren 2015 Fuel (a) $ 173 $ — $ 173 Gas stored underground 10 87 97 Other materials and supplies 204 64 268 Total materials and supplies $ 387 $ 151 $ 538 2014 Fuel (a) $ 134 $ — $ 134 Gas stored underground 16 111 127 Other materials and supplies 197 66 263 Total materials and supplies $ 347 $ 177 $ 524 (a) Consists of coal, oil, and propane. Purchased Gas, Power and Fuel Rate-adjustment Mechanisms Ameren Missouri and Ameren Illinois have various rate-adjustment mechanisms in place that provide for the recovery of purchased natural gas and electric fuel and purchased power costs without a traditional rate case proceeding. See Note 2 – Rate and Regulatory Matters for the regulatory assets and liabilities recorded at December 31, 2015 and 2014 , related to the rate-adjustment mechanisms discussed below. In Ameren Missouri’s and Ameren Illinois’ natural gas utility jurisdictions, changes in natural gas costs are reflected in billings to their natural gas utility customers through PGA clauses. The difference between actual natural gas costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to natural gas utility customers in a subsequent period. In Ameren Illinois’ retail electric utility jurisdiction, changes in purchased power and transmission service costs are reflected in billings to its electric utility customers through pass-through rate-adjustment clauses. The difference between actual purchased power and transmission service costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to electric utility customers in a subsequent period. Ameren Missouri has a FAC that allows an adjustment of electric rates three times per year for a pass-through to customers of 95% of changes in fuel and purchased power costs, including transportation charges and revenues, net of off-system sales, greater or less than the amount set in base rates, subject to MoPSC prudence review. The difference between the actual amounts incurred for these items and the amounts recovered from Ameren Missouri customers' base rates is deferred as a regulatory asset or liability. The deferred amounts are either billed or refunded to electric utility customers in a subsequent period. As of May 30, 2015, transmission revenues and substantially all transmission charges are excluded from net energy costs as a result of the April 2015 MoPSC electric rate order. Property and Plant, Net We capitalize the cost of additions to and betterments of units of property and plant. The cost includes labor, material, applicable taxes, and overhead. An allowance for funds used during construction, as discussed below, is also capitalized as a cost of our rate-regulated assets. Maintenance expenditures, including nuclear refueling and maintenance outages, are expensed as incurred. When units of depreciable property are retired, the original costs, less salvage values, are charged to accumulated depreciation. If environmental expenditures are related to assets currently in use, as in the case of the installation of pollution control equipment, the cost is capitalized and depreciated over the expected life of the asset. See Asset Retirement Obligations below and Note 3 – Property and Plant, Net, for additional information. Depreciation Depreciation is provided over the estimated lives of the various classes of depreciable property by applying composite rates on a straight-line basis to the cost basis of such property. The provision for depreciation for the Ameren Companies in 2015 , 2014 , and 2013 ranged from 3% to 4% of the average depreciable cost. Allowance for Funds Used During Construction We capitalize allowance for funds used during construction, or the cost of borrowed funds and the cost of equity funds (preferred and common shareholders’ equity) applicable to rate-regulated construction expenditures, in accordance with the utility industry's accounting practice. Allowance for funds used during construction does not represent a current source of cash funds. This accounting practice offsets the effect on earnings of the cost of financing during construction, and it treats such financing costs in the same manner as construction charges for labor and materials. Under accepted ratemaking practice, cash recovery of allowance for funds used during construction and other construction costs occurs when completed projects are placed in service and reflected in customer rates. The following table presents the annual allowance for funds used during construction rates that were applied to construction projects in 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri 7 % 7 % 8 % Ameren Illinois 6 % 2 % 8 % Goodwill Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired. Ameren and Ameren Illinois' carrying amount of goodwill was $411 million at December 31, 2015 , and 2014 . All of Ameren's and Ameren Illinois' goodwill at December 31, 2015 and 2014 , was assigned to the Ameren Illinois reporting unit. We evaluate goodwill for impairment as of October 31 each year, or more frequently if events and circumstances change that would more likely than not reduce the fair value of the Ameren Illinois reporting unit below its carrying amount. Entities assessing goodwill for impairment have the option of first performing a qualitative assessment before calculating the fair value of the reporting unit. If an entity determines, on the basis of qualitative factors, that the fair value of the reporting unit is more likely than not less than the carrying amount, a two-step quantitative test is required. An entity has the option to bypass the qualitative assessment in any period and proceed directly to the first step of the quantitative test, which compares the fair value of the reporting unit to its carrying amount. If the carrying amount of the reporting unit exceeds its estimated fair value, the entity performs the second step, which requires an assignment of the reporting unit's fair value to the individual assets and liabilities in order to determine the implied fair value of the reporting unit's goodwill. If the implied fair value of goodwill is less than its carrying amount, an impairment loss is recorded. Ameren and Ameren Illinois elected to bypass the qualitative assessment and completed the first step of the quantitative test as of October 31, 2015 . Based on the results, Ameren and Ameren Illinois determined that the estimated fair value of the Ameren Illinois reporting unit significantly exceeded its carrying value as of October 31, 2015 , indicating no impairment of Ameren’s or Ameren Illinois’ goodwill. Ameren's and Ameren Illinois' valuation approach is based on a market participant view. It uses a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in estimating the fair value of the Ameren Illinois reporting unit include discount and growth rates, utility sector market performance and transactions, and projected operating results and cash flows. The goodwill assigned to the Ameren Illinois reporting unit on the December 31, 2015 balance sheets of Ameren and Ameren Illinois had no accumulated goodwill impairment losses. Ameren and Ameren Illinois will continue to monitor internal and external factors for signs of possible declines in estimated fair value and potential goodwill impairment. Impairment of Long-lived Assets We evaluate long-lived assets classified as held and used for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Whether an impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets to the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, we recognize an impairment charge equal to the amount by which the carrying value exceeds the estimated fair value of the assets. In the period in which we determine an asset meets held for sale criteria, we record an impairment charge to the extent the book value exceeds its estimated fair value less cost to sell. We did not identify any events or changes in circumstances that indicated that the carrying value of long-lived assets may not be recoverable in 2015 and 2014 . Environmental Costs Liabilities for environmental costs are recorded on an undiscounted basis when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated. Costs are expensed or deferred as a regulatory asset when it is expected that the costs will be recovered from customers in future rates. Asset Retirement Obligations We are required to record the estimated fair value of legal obligations associated with the retirement of tangible long-lived assets in the period in which the liabilities are incurred and to capitalize a corresponding amount as part of the book value of the related long-lived asset. In subsequent periods, we are required to make adjustments to AROs based on changes in the estimated fair values of the obligations. Corresponding increases in asset book values are depreciated over the remaining useful life of the related asset. Uncertainties as to the probability, timing, or amount of cash expenditures associated with AROs affect our estimates of fair value. Ameren and Ameren Missouri have recorded AROs for retirement costs associated with Ameren Missouri’s Callaway energy center decommissioning costs, CCR facilities, and river structures. Also, Ameren, Ameren Missouri, and Ameren Illinois have recorded AROs for retirement costs associated with asbestos removal and the disposal of certain transformers. Ameren and Ameren Missouri have a nuclear decommissioning trust fund for the decommissioning of the Callaway energy center. Asset removal costs accrued by our rate-regulated operations that do not constitute legal obligations are classified as regulatory liabilities. See Note 2 – Rate and Regulatory Matters. The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the years ended December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Ameren Balance at December 31, 2013 $ 366 $ 3 $ 369 Liabilities incurred 2 — 2 Liabilities settled (2 ) (a) (2 ) Accretion in 2014 (b) 21 (a) 21 Change in estimates (c) 2 4 6 Balance at December 31, 2014 $ 389 $ 7 (d) $ 396 Liabilities incurred 3 — 3 Liabilities settled (1 ) (1 ) (2 ) Accretion in 2015 (b) 23 (a) 23 Change in estimates (e) 203 (a) 203 Balance at December 31, 2015 $ 617 (f) $ 6 (d) $ 623 (f) (a) Less than $1 million. (b) Accretion expense was recorded as an increase to regulatory assets at Ameren Missouri and Ameren Illinois. (c) The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren Illinois changed its fair value estimate for asbestos removal. (d) Included in “Other deferred credits and liabilities” on the balance sheet. (e) The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren and Ameren Missouri increased their AROs related to the decommissioning of the Callaway energy center by $99 million to reflect the 2015 cost study and funding analysis filed with the MoPSC, the extension of the estimated operating life until 2044, and a reduction in the discount rate assumption. See Note 10 – Callaway Energy Center for additional information. In addition, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $100 million to their AROs associated with CCR storage facilities. See Note 15 – Commitments and Contingencies for additional information. Ameren and Ameren Missouri also increased their AROs by $4 million due to a change in the estimated retirement dates of the Meramec and Rush Island energy centers as a result of the MoPSC's April 2015 electric rate order. (f) Balance included $5 million in "Other current liabilities" on the balance sheet as of December 31, 2015. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the AROs related to the abandoned Meredosia and Hutsonville energy centers, which are presented as discontinued operations and therefore not included in the table above. Noncontrolling Interests As of December 31, 2015 and 2014 , Ameren’s noncontrolling interests included the preferred stock of Ameren Missouri and Ameren Illinois. Operating Revenue The Ameren Companies record operating revenue for electric or natural gas service when it is delivered to customers. We accrue an estimate of electric and natural gas revenues for service rendered but unbilled at the end of each accounting period. Ameren Illinois participates in the performance-based formula ratemaking framework pursuant to the IEIMA. In addition, Ameren Illinois' and ATXI's electric transmission delivery service operating revenues are regulated by the FERC. The provisions of the IEIMA and the FERC's electric transmission formula rate framework provide for annual reconciliations of the electric delivery and electric transmission service revenue requirements necessary to reflect the actual recoverable costs incurred in a given year with the revenue requirements in customer rates for that year, including an allowed return on equity. In each of those electric jurisdictions, if the current year's revenue requirement is greater than the revenue requirement reflected in that year's customer rates, an increase to electric operating revenues with an offset to a regulatory asset is recorded to reflect the expected recovery of those additional amounts from customers within the next two years. In each jurisdiction, if the current year's revenue requirement is less than the revenue requirement reflected in that year's customer rates, a reduction to electric operating revenues with an offset to a regulatory liability is recorded to reflect the expected refund to customers within the next two years. See Note 2 – Rate and Regulatory Matters for information regarding Ameren Illinois' revenue requirement reconciliation pursuant to the IEIMA. Accounting for MISO Transactions MISO-related purchase and sale transactions are recorded by Ameren, Ameren Missouri, and Ameren Illinois using settlement information provided by MISO. Ameren Missouri records these purchase and sale transactions on a net hourly position. Ameren Missouri records net purchases in a single hour in “Operating Expenses – Purchased power” and net sales in a single hour in “Operating Revenues – Electric” in its statement of income. Ameren Illinois records net purchases in “Operating Expenses – Purchased power” in its statement of income to reflect all of its MISO transactions relating to the procurement of power for its customers. On occasion, Ameren Missouri's and Ameren Illinois' prior-period transactions will be resettled outside the routine settlement process because of a change in MISO’s tariff or a material interpretation thereof. In these cases, Ameren Missouri and Ameren Illinois recognize expenses associated with resettlements once the resettlement is probable and the resettlement amount can be estimated and recognize revenues once the resettlement amount is received. Nuclear Fuel Ameren Missouri’s cost of nuclear fuel is capitalized and then amortized to fuel expense on a unit-of-production basis. The cost is charged to "Operating Expenses – Fuel" in the statement of income. Stock-based Compensation Stock-based compensation cost is measured at the grant date based on the fair value of the award, net of an assumed forfeiture rate. Ameren recognizes as compensation expense the estimated fair value of stock-based compensation on a straight-line basis over the requisite service period. See Note 12 – Stock-based Compensation for additional information. Excise Taxes Ameren Missouri and Ameren Illinois collect from their customers certain excise taxes that are levied on the sale or distribution of natural gas and electricity. Excise taxes are levied on Ameren Missouri's electric and natural gas businesses and on Ameren Illinois' natural gas business. They are recorded gross in “Operating Revenues – Electric,” “Operating Revenues – Gas,” and “Operating Expenses – Taxes other than income taxes” on the statement of income or the statement of income and comprehensive income. Excise taxes for electric service in Illinois are levied on customers and are therefore not included in Ameren Illinois' revenues and expenses. The following table presents the excise taxes recorded in “Operating Revenues – Electric,” “Operating Revenues – Gas,” and “Operating Expenses – Taxes other than income taxes” for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri $ 156 $ 151 $ 152 Ameren Illinois 57 64 61 Ameren $ 213 $ 215 $ 213 Unamortized Debt Discounts, Premiums, and Issuance Costs Long-term debt discounts, premiums, and issuance costs are amortized over the lives of the related issuances. Credit facility fees are amortized over the credit facility term. Income Taxes Ameren uses an asset and liability approach for its financial accounting and reporting of income taxes, in accordance with authoritative accounting guidance. Deferred tax assets and liabilities are recognized for transactions that are treated differently for financial reporting and income tax return purposes. These deferred tax assets and liabilities are based on statutory tax rates. We recognize that regulators will probably reduce future revenues for deferred tax liabilities that were initially recorded at rates in excess of the current statutory rate. Therefore, reductions in deferred tax liabilities that were recorded because of decreases in the statutory rate have been credited to a regulatory liability. A regulatory asset has been established to recognize the probable recovery through future customer rates of tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate changes. Investment tax credits used on tax returns for prior years have been deferred as a noncurrent liability. The credits are being amortized over the useful lives of the related investment. Deferred income taxes were recorded on the temporary difference represented by the deferred investment tax credits and a corresponding regulatory liability. This recognizes the expected reduction in rates for future lower income taxes associated with the amortization of the investment tax credits. See Note 13 – Income Taxes. Ameren Missouri, Ameren Illinois, and all the other Ameren subsidiary companies are parties to a tax allocation agreement with Ameren (parent) that provides for the allocation of consolidated tax liabilities. The tax allocation agreement specifies that each party be allocated an amount of tax similar to that which would be owed or refunded had the party been separately subject to tax. Any net benefit attributable to the parent is reallocated to the other parties. This reallocation is treated as a capital contribution to the party receiving the benefit. Earnings per Share Basic earnings per share is computed by dividing net income attributable to Ameren common shareholders by the weighted-average number of common shares outstanding during the period. Earnings per diluted share is computed by dividing net income attributable to Ameren common shareholders by the weighted-average number of diluted common shares outstanding during the period. Earnings per diluted share reflects the potential dilution that would occur if certain stock-based performance share units were settled. The number of performance share units assumed to be settled was 1.0 million , 1.8 million , and 1.9 million for the years ended December 31, 2015 , 2014 , and 2013 , respectively. There were no potentially dilutive securities excluded from the diluted earnings per share calculations for the years ended December 31, 2015 , 2014 , and 2013 . Capital Contributions and Return of Capital In 2015, Ameren Missouri and Ameren Illinois received cash capital contributions of $224 million and $25 million , respectively, from Ameren (parent) as a result of the tax allocation agreement. Additionally, as of December 31, 2015, Ameren Missouri accrued a $38 million capital contribution related to the same agreement. In 2014, Ameren Missouri and Ameren Illinois received cash capital contributions of $215 million and $15 million , respectively, from Ameren (parent) as a result of the tax allocation agreement. Additionally, as of December 31, 2014, Ameren Missouri accrued a $9 million capital contribution related to the same agreement. Also in 2014, Ameren Missouri returned capital of $215 million to Ameren (parent). Supplemental Cash Flow Information The following table presents additional information regarding Ameren's consolidated statement of cash flows for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Cash paid (refunded) during the year: Interest Continuing operations (a) $ 335 $ 333 $ 362 Discontinued operations (b) — — 31 $ 335 $ 333 $ 393 Income taxes, net Continuing Operations $ (17 ) $ (41 ) $ 116 Discontinued Operations 2 14 (108 ) $ (15 ) $ (27 ) $ 8 (a) Net of $17 million , $18 million , and $20 million capitalized, respectively. (b) Net of $- million, $- million, and $17 million capitalized, respectively. See Note 3 – Property and Plant, Net, for information on accrued capital expenditures. Accounting Changes and Other Matters The following is a summary of recently adopted authoritative accounting guidance, as well as guidance issued but not yet adopted, that could affect the Ameren Companies. Revenue from Contracts with Customers In May 2014, the FASB issued authoritative accounting guidance that changes the criteria for recognizing revenue from a contract with a customer. The underlying principle of the guidance is that an entity will recognize revenue for the transfer of promised goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The guidance also requires additional disclosures to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. Entities can apply the guidance retrospectively to each reporting period presented or retrospectively by recording a cumulative effect adjustment to retained earnings in the period of initial adoption. The Ameren Companies are currently assessing the impacts of this guidance on their results of operations, financial position, and disclosures, including their accounting for contributions in aid of construction and similar arrangements, as well as the transition method that they will use to adopt the guidance. In August 2015, the FASB deferred the effective date of this revenue guidance to the first quarter of 2018, with an option for entities to early adopt in the first quarter of 2017. The Ameren Companies do not expect to early adopt this guidance. Amendments to the Consolidation Analysis In February 2015, the FASB issued authoritative accounting guidance that amends the consolidation analysis for variable interest entities and voting interest entities. The new guidance affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. The guidance is effective for the Ameren Companies in the first quarter of 2016, and can be applied retrospectively to each reporting period presented or retrospectively by recording a cumulative effect adjustment to retained earnings in the period of initial adoption. The Ameren Companies are currently assessing this guidance and do not expect any material impacts to their results of operations, financial position or cash flows. Presentation of Debt Issuance Costs In April 2015, the FASB issued authoritative accounting guidance to simplify the presentation of debt issuance costs in the balance sheet. The guidance requires debt issuance costs to be presented as a reduction to the associated debt liability. Previously, debt issuance costs were presented in "Other assets" on the Ameren Companies' balance sheets. The Ameren Companies early adopted this standard in 2015 and applied the guidance retrospectively. At December 31, 2015, debt issuance costs of $43 million , $19 million , and $18 million were presented in "Long-term debt, net" on Ameren's, Ameren Missouri's, and Ameren Illinois' balance sheets, respectively. At December 31, 2014, debt issuance costs of $35 million , $18 million , and $17 million previously presented in "Other assets" on Ameren's, Ameren Missouri's, and Ameren Illinois' respective balance sheets were reclassi |
Rate And Regulatory Matters
Rate And Regulatory Matters | 12 Months Ended |
Dec. 31, 2015 | |
Public Utilities, General Disclosures [Abstract] | |
RATE AND REGULATORY MATTERS | RATE AND REGULATORY MATTERS Below is a summary of significant regulatory proceedings and related lawsuits. We are unable to predict the ultimate outcome of these matters, the timing of the final decisions of the various agencies and courts, or the effect on our results of operations, financial position, or liquidity. Missouri 2015 Electric Rate Order In April 2015, the MoPSC issued an order approving a $122 million increase in Ameren Missouri’s annual revenues for electric service, including $109 million related to the increase in net energy costs above those included in base rates previously authorized by the MoPSC. The revenue increase was based on a 9.53% return on common equity, a capital structure composed of 51.8% common equity, and a rate base of $7.0 billion to reflect investments through December 31, 2014. Rate changes consistent with the order became effective on May 30, 2015. The order approved Ameren Missouri’s request for continued use of the FAC; however, it changed the FAC to exclude all transmission revenues and substantially all transmission charges. The order did not approve the continued use of the regulatory tracking mechanisms for storm costs or for vegetation management and infrastructure inspection costs. These changes to Ameren Missouri’s recovery mechanisms are expected to contribute to regulatory lag. The order did approve the continued use of the regulatory tracking mechanisms for pension and other postretirement benefits, renewable energy standard costs, solar rebates, and uncertain tax positions that the MoPSC authorized in prior electric rate orders. In addition, the order approved a reduction to Noranda’s electric rates with an offsetting increase in electric rates for Ameren Missouri’s other customers. The rate shift is designed to be revenue neutral for Ameren Missouri. In June 2015, Ameren Missouri filed an appeal with the Missouri Court of Appeals, Western District, concerning the reduction to Noranda’s electric rates included in the MoPSC’s order. In February 2016, Ameren Missouri withdrew its appeal. MEEIA The MEEIA established a regulatory framework that, among other things, requires the MoPSC to ensure that a utility’s financial incentives are aligned to help customers use energy more efficiently, to provide timely cost recovery, and to provide earnings opportunities associated with cost-effective energy efficiency programs. Missouri does not have a law mandating energy efficiency programs. In August 2012, the MoPSC approved Ameren Missouri’s customer energy efficiency programs, net shared benefits, and performance incentive for 2013 through 2015. From 2013 through 2015, Ameren Missouri invested $134 million in customer energy efficiency programs and realized $174 million of net shared benefits. The MoPSC also established a performance incentive that would provide Ameren Missouri an opportunity to earn additional revenues by achieving certain customer energy efficiency goals, including $19 million if 100% of the goals were achieved during the three -year period, with the potential to earn a larger performance incentive if Ameren Missouri’s energy savings exceeded those goals. In June 2015, the MoPSC staff filed a complaint case with the MoPSC regarding the method and inputs used in calculating the performance incentive for 2014 and 2015. In November 2015, the MoPSC issued an order that adopted the MoPSC staff’s method and inputs used in calculating the performance incentive for 2014 and 2015. Ameren Missouri filed an appeal of the order with the Missouri Court of Appeals, Western District. If the Missouri Court of Appeals upholds the MoPSC order, the performance incentive awarded from the 2014 and 2015 MEEIA programs will be significantly less than the performance incentive calculated using Ameren Missouri’s interpretation. Ameren Missouri has not recorded revenues associated with the performance incentive for any of the MEEIA program years. Ameren Missouri believes that it will ultimately be found to have exceeded 100% of the customer energy efficiency goals, and it therefore expects to recognize revenues of at least $19 million in 2016. In February 2016, the MoPSC issued an order approving Ameren Missouri's March 2016 to February 2019 MEEIA plan which included a portfolio of customer energy efficiency programs along with a rider to collect the program costs, the throughput disincentive, and a performance incentive from customers. The throughput disincentive recovery will replace the net shared benefits that were collected under the 2013 through 2015 MEEIA plan. The MEEIA rider will allow Ameren Missouri to collect the throughput disincentive without a traditional rate proceeding, until such time as lower volumes resulting from the MEEIA programs are reflected in base rates. Customer rates will be based upon both forecasted program costs and throughput disincentive which will be annually reconciled to actual results. Beginning in March 2016, Ameren Missouri intends to invest $158 million over the three -year period in customer energy efficiency programs. In addition, similar to the MEEIA plan that ended in December 2015, the MoPSC's order approved a performance incentive that would provide Ameren Missouri an opportunity to earn additional revenues by achieving certain customer energy efficiency goals, including $27 million if 100% of the goals are achieved during the three -year period, with the potential to earn more if Ameren Missouri's energy savings exceed those goals. Ameren Missouri must achieve at least 25% of its energy efficiency goals before it earns a performance incentive. Noranda Ameren Missouri supplies electricity to Noranda’s aluminum smelter located in southeast Missouri under a long-term power supply agreement. In May 2015, Ameren Missouri notified Noranda of its intent to terminate the agreement effective June 1, 2020. If Ameren Missouri wants to cease providing electricity to Noranda following the termination date, Ameren Missouri would also be required to obtain approval from the MoPSC. On January 8, 2016, Noranda announced that production had been idled at two of its three pot lines at the smelter following an electric supply circuit failure on assets not owned by Ameren Missouri. On January 13, 2016, Noranda announced that the smelter’s “remaining operations will be curtailed on or before March 12, 2016, unless [Noranda] is able to secure a substantially more sustainable power rate for the smelter and materially improve [Noranda’s] overall liquidity.” Ameren Missouri has been working with Noranda, legislators and other stakeholders on a potential legislative solution to support Noranda’s operations. In its April 2015 electric rate order, the MoPSC approved a rate design that established $78 million in annual revenues, net of fuel and purchased power costs, as Noranda’s portion of Ameren Missouri’s revenue requirement. The portion of Ameren Missouri’s annual revenue requirement reflected in Noranda’s electric rate is based on the smelter using approximately 4.2 million megawatthours annually, which is almost 100% of its operating capacity. Ameren Missouri’s rates, including those for Noranda, are seasonal. Noranda’s summer base rate (June through September) is $45.78 per megawatthour and its winter base rate (October through May) is $31.11 per megawatthour. In 2016, actual sales volumes to Noranda will be significantly below the sales volumes reflected in rates. As a result, Ameren Missouri will not fully recover its revenue requirement until rates are adjusted by the MoPSC in a future electric rate case to accurately reflect Noranda’s actual sales volumes. In light of the Noranda announcements described above, Ameren Missouri expects to employ a provision in its FAC tariff that, under certain circumstances, allows Ameren Missouri to retain a portion of the revenues from any off-system sales it makes as a result of reduced tariff sales to Noranda. The current market price of electricity is less than Noranda’s electric rate, and Ameren Missouri expects market prices to remain below Noranda’s electric rate during 2016. Accordingly, this FAC provision would not enable Ameren Missouri to fully recover its revenue requirement under current market conditions. Although Ameren Missouri has not decided when to file its next electric rate case, on January 11, 2016, Ameren Missouri filed a notice with the MoPSC, that would enable Ameren Missouri to file a rate case after 60 days . Ameren Missouri expects to file a rate case in 2016 and expects the resulting new rates to reflect Noranda’s actual sales volumes which would prospectively eliminate the impact of the current revenue shortfall. The rate case would take place over a period of up to 11 months from the date of filing. Ameren Missouri may seek recovery of lost revenues in a filing with the MoPSC for certain costs incurred but not contemporaneously recovered as a result of Noranda's reduced operations. Ameren Missouri will continue to monitor Noranda’s sales volumes and to evaluate regulatory and legislative options that might mitigate adverse financial impacts. The reduction in Noranda’s sales volumes will adversely affect Ameren’s and Ameren Missouri’s results of operations, financial condition, and liquidity until customer rates are adjusted in a future rate case. On February 8, 2016, Noranda filed voluntary petitions for a court-supervised restructuring process under Chapter 11 of the United States Bankruptcy Code. In the filing, Noranda reaffirmed that the remaining pot line will continue to operate at the smelter until March 2016, at which time operation of the line will be curtailed. Noranda stated it would maintain the flexibility to restart operations at the smelter should conditions allow. For utility service through February 8, 2016, Noranda had prepaid an amount to Ameren Missouri in excess of its utility service usage. Ameren Missouri expects to be paid in full for utility services provided after February 8, 2016. ATXI Transmission Projects In May 2015, the MoPSC granted ATXI a certificate of convenience and necessity for the seven -mile portion of the Illinois Rivers project located in Missouri. In June 2015, ATXI made a filing with the MoPSC requesting a certificate of convenience and necessity for the Mark Twain project. The Mark Twain project is a MISO-approved 100 -mile transmission line located in northeast Missouri. A decision is expected from the MoPSC in 2016. Illinois IEIMA Under the provisions of the IEIMA's performance-based formula rate-making framework, which currently extends through 2019, Ameren Illinois’ electric delivery service rates are subject to an annual revenue requirement reconciliation to its actual recoverable costs. Throughout each year, Ameren Illinois records a regulatory asset or a regulatory liability and a corresponding increase or decrease to operating revenues for any differences between the revenue requirement reflected in customer rates for that year and its estimate of the probable increase or decrease in the revenue requirement expected to ultimately be approved by the ICC based on that year's actual recoverable costs incurred. As of December 31, 2015 , Ameren Illinois had recorded regulatory assets of $62 million and $103 million , including interest, to reflect its expected 2015 and the 2014 approved revenue requirement reconciliation adjustments, respectively. As of December 31, 2014 , Ameren Illinois had recorded a $65 million regulatory asset to reflect its approved 2013 revenue requirement reconciliation adjustment, which was collected, with interest, from customers during 2015. In December 2015, the ICC issued an order in Ameren Illinois’ annual update filing approving a $106 million increase in Ameren Illinois’ electric delivery service revenue requirement beginning in January 2016. This update reflects an increase to the annual formula rate based on 2014 actual recoverable costs and expected net plant additions for 2015, an increase to include the 2014 revenue requirement reconciliation adjustment, which was recorded as a regulatory asset at December 31, 2015, and a decrease for the conclusion of the 2013 revenue requirement reconciliation adjustment, which was fully collected from customers in 2015. In December 2013, the ICC issued an order that disallowed, in part, the recovery from customers of the debt premium costs paid by Ameren Illinois for a tender offer in August 2012 to repurchase outstanding senior secured notes. As a result of the ICC order, in 2013, Ameren and Ameren Illinois each recorded a pretax charge to earnings of $15 million relating to the partial disallowance of the debt premium costs. In December 2014, the ICC issued an order that allowed partial recovery from customers of the previously disallowed debt premium costs. Accordingly, in 2014, Ameren and Ameren Illinois each recorded a pretax increase to earnings of $11 million to reflect the partial recovery of the debt premium costs. Ameren and Ameren Illinois recorded the effects of the 2013 and 2014 orders to "Interest charges" with a corresponding offset to "Regulatory assets." 2015 Natural Gas Delivery Service Rate Order In December 2015, the ICC issued a rate order that approved an increase in revenues for Ameren Illinois' natural gas delivery service of $45 million . The revenue increase was based on a 9.6% return on common equity, a capital structure composed of 50% common equity, and a rate base of $1.2 billion . The rate order was based on a 2016 future test year. The rate changes were in effect in January 2016. In addition, the rate order approved the VBA for residential and small nonresidential customers beginning in 2016. 2015 ICC Purchased Power Reconciliation In January 2015, the ICC issued an order that approved Ameren Illinois' reconciliation of revenues collected under its purchased power rider mechanism and Ameren Illinois' related cumulative power usage cost. In the first quarter of 2015, based on the January 2015 order, both Ameren and Ameren Illinois recorded a $15 million increase to electric revenues for the recovery of this cumulative power usage cost from electric customers. ATXI Transmission Project The Spoon River project is a MISO-approved 46 -mile transmission line to be constructed in northwest Illinois. In September 2015, the ICC granted a certificate of public convenience and necessity and project approval for the Spoon River project. Federal Ameren Illinois Electric Transmission Rate Refund In July 2012, the FERC issued an order concluding that Ameren Illinois improperly included acquisition premiums, including goodwill, in determining the common equity used in its electric transmission formula rate and thereby inappropriately recovered a higher amount from its electric transmission customers. The order required Ameren Illinois to make refunds to customers for such improperly included amounts. In July 2015, the FERC approved a settlement agreement between Ameren Illinois and the affected customers. The settlement agreement required Ameren Illinois to make refunds and payments of $8 million to electric transmission customers, all of which was paid in 2015. The settlement agreement also required Ameren Illinois to take other actions, such as reducing common equity for electric transmission ratemaking purposes on a prospective basis. The transmission rates that became effective on January 1, 2016, reflect these adjustments. FERC Complaint Cases In November 2013, a customer group filed a complaint case with the FERC seeking a reduction in the allowed base return on common equity for the FERC-regulated transmission rate base under the MISO tariff from 12.38% to 9.15% . In December 2015, an administrative law judge issued an initial decision in the November 2013 complaint case that would lower the allowed base return on common equity to 10.32% and would require customer refunds to be issued for the 15-month period ending February 2015. The allowed base return on common equity in the initial decision was based on multiple inputs, including observable market data for the six months ended June 30, 2015. The FERC is expected to issue a final order on the November 2013 complaint case by October 2016. As the maximum FERC-allowed refund period for the November 2013 complaint case ended in February 2015, another customer complaint case was filed in February 2015. The February 2015 complaint case seeks a reduction in the allowed base return on common equity for the FERC-regulated transmission rate base under the MISO tariff to 8.67% . The initial decision from an administrative law judge in the February 2015 complaint case, which will subsequently require FERC approval, is expected to be issued by June 2016. On January 6, 2015, a FERC-approved incentive adder of up to 50 basis points on the allowed base return on common equity for our participation in an RTO became effective. Beginning with its January 6, 2015 effective date, the incentive adder will reduce any refund to customers relating to a reduction of the allowed base return on common equity from the complaint cases discussed above. As of December 31, 2015, Ameren and Ameren Illinois had current regulatory liabilities of $45 million and $32 million , respectively, representing their estimates of the potential refunds from the November 12, 2013 refund effective date through December 31, 2015. Ameren and Ameren Illinois recorded liabilities to reflect the allowed base return on common equity in the initial decision for the November 2013 complaint case refund period, and the observable market data for the six months ended December 31, 2015, for the February 2015 complaint case refund period. Ameren’s and Ameren Illinois’ liabilities also reflect the January 6, 2015 incentive adder discussed above. Ameren Missouri did not record a liability as of December 31, 2015, and it does not expect that a reduction in the FERC-allowed base return on common equity for MISO transmission owners would be material to its results of operations, financial position, or liquidity. Combined Construction and Operating License In 2008, Ameren Missouri filed an application with the NRC for a COL for a second nuclear unit at Ameren Missouri's existing Callaway County, Missouri, energy center site. In 2009, Ameren Missouri suspended its efforts to build a second nuclear unit at its existing Callaway site, and the NRC suspended review of the COL application. Prior to suspending its efforts, Ameren Missouri had capitalized $69 million related to the project. Primarily because of changes in vendor support for licensing efforts at the NRC, Ameren Missouri’s assessment of long-term capacity needs, declining costs of alternative generation technologies, and the regulatory framework in Missouri, Ameren Missouri discontinued its efforts to license and build a second nuclear unit at its existing Callaway site. As a result of this decision, in the second quarter of 2015, Ameren and Ameren Missouri recognized a $69 million noncash pretax provision for all of the previously capitalized COL costs. Ameren Missouri has withdrawn its COL application with the NRC. Regulatory Assets and Liabilities In accordance with authoritative accounting guidance regarding accounting for the effects of certain types of regulation, we defer certain costs as regulatory assets pursuant to actions of regulators or because we expect to recover such costs in rates charged to customers. We may also defer certain amounts as regulatory liabilities because of actions of regulators or because we expect that such amounts will be returned to customers in future rates. The following table presents our regulatory assets and regulatory liabilities at December 31, 2015 and 2014 : 2015 2014 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Current regulatory assets: Under-recovered FAC (a)(b) $ 37 $ — $ 37 $ 128 $ — $ 128 Under-recovered Illinois electric power costs (c) — 3 3 — 2 2 Under-recovered PGA (c) — 8 8 — 20 20 MTM derivative losses (d) 29 45 74 32 42 74 Energy efficiency riders (e) 23 — 23 3 — 3 IEIMA revenue requirement reconciliation adjustment (a)(f) — 103 103 — 65 65 FERC revenue requirement reconciliation adjustment (a)(g) — 8 12 — — 3 Total current regulatory assets $ 89 $ 167 $ 260 $ 163 $ 129 $ 295 Noncurrent regulatory assets: Pension and postretirement benefit costs (h) $ 95 $ 202 $ 297 $ 148 $ 275 $ 423 Income taxes (i) 254 4 258 253 3 256 Asset retirement obligations (j) — 4 4 — 5 5 Callaway costs (a)(k) 32 — 32 36 — 36 Unamortized loss on reacquired debt (a)(l) 69 69 138 72 80 152 Contaminated facilities costs (m) — 230 230 — 251 251 MTM derivative losses (d) 15 175 190 14 144 158 Storm costs (a)(n) — 9 9 — 3 3 Demand-side costs before the MEEIA implementation (a)(o) 31 — 31 44 — 44 Workers’ compensation claims (p) 6 7 13 7 7 14 Credit facilities fees (q) 4 — 4 5 — 5 Construction accounting for pollution control equipment (a)(r) 20 — 20 21 — 21 Solar rebate program (a)(s) 74 — 74 88 — 88 IEIMA revenue requirement reconciliation adjustment (a)(f) — 62 62 — 101 101 FERC revenue requirement reconciliation adjustment (a)(g) — 5 11 — 8 12 Other 5 4 9 7 6 13 Total noncurrent regulatory assets $ 605 $ 771 $ 1,382 $ 695 $ 883 $ 1,582 Current regulatory liabilities: Over-recovered FAC (b) $ 9 $ — $ 9 $ — $ — $ — Over-recovered Illinois electric power costs (c) — 6 6 — 26 26 Over-recovered PGA (c) 3 — 3 2 25 27 MTM derivative gains (d) 16 1 17 16 1 17 FERC revenue requirement reconciliation adjustment (g) — — — — 11 11 Estimated refund for FERC complaint cases, orders, and audit findings (t) — 32 45 — 21 25 Total current regulatory liabilities $ 28 $ 39 $ 80 $ 18 $ 84 $ 106 Noncurrent regulatory liabilities: Income taxes (u) $ 36 $ 6 $ 42 $ 41 $ 14 $ 55 Uncertain tax positions tracker (v) 6 — 6 7 — 7 Removal costs (w) 933 671 1,605 886 643 1,529 Asset retirement obligation (j) 167 — 167 182 — 182 Bad debt riders (x) — 6 6 — 7 7 Pension and postretirement benefit costs tracker (y) 19 — 19 24 — 24 Energy efficiency riders (e) — 36 36 — 39 39 Renewable energy credits (z) — 12 12 1 — 1 Storm tracker (aa) 9 — 9 6 — 6 Other 2 1 3 — — — Total noncurrent regulatory liabilities $ 1,172 $ 732 $ 1,905 $ 1,147 $ 703 $ 1,850 (a) These assets earn a return. (b) Under-recovered or over-recovered fuel costs to be recovered or refunded through the FAC. Specific accumulation periods aggregate the under-recovered or over-recovered costs over four months, any related adjustments that occur over the following four months, and the recovery from or refund to customers that occurs over the next eight months. (c) Under-recovered or over-recovered costs from utility customers. Amounts will be recovered from, or refunded to, customers within one year of the deferral. (d) Deferral of commodity-related derivative MTM losses or gains. See Note 7 – Derivative Financial Instruments for additional information. (e) The Ameren Missouri balance relates to the MEEIA. Beginning in January 2014, the MEEIA rider allowed Ameren Missouri to collect from or refund to customers any annual difference in the actual amounts incurred and the amounts collected from customers for the MEEIA program costs and its net shared benefits. Under the MEEIA rider, collections from or refunds to customers occur one year after the program costs and lost revenues are incurred. The Ameren Illinois balance relates to a regulatory tracking mechanism to recover its electric and natural gas costs associated with developing, implementing, and evaluating customer energy efficiency and demand response programs. Any under-recovery or over-recovery will be collected from or refunded to customers over the 12 months following the plan year. (f) The difference between Ameren Illinois' annual revenue requirement calculated under the IEIMA's performance-based formula ratemaking framework and the revenue requirement included in customer rates for that year. Subject to ICC approval, these amounts will be collected from or refunded to customers with interest within two years. (g) Ameren Illinois' and ATXI's annual revenue requirement reconciliation adjustments calculated pursuant to the FERC's electric transmission formula ratemaking framework. The under-recovery or over-recovery will be recovered from or refunded to customers within two years. (h) These costs are being amortized in proportion to the recognition of prior service costs (credits) and actuarial losses (gains) attributable to Ameren’s pension plan and postretirement benefit plans. See Note 11 – Retirement Benefits for additional information. (i) Tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate changes. This will be recovered over the expected life of the related assets. (j) Recoverable or refundable removal costs for AROs, including net realized and unrealized gains and losses related to the nuclear decommissioning trust fund investments. See Note 1 – Summary of Significant Accounting Policies – Asset Retirement Obligations and Investments. (k) Ameren Missouri’s Callaway energy center operations and maintenance expenses, property taxes, and carrying costs incurred between the plant in-service date and the date the plant was reflected in rates. These costs are being amortized over the remaining life of the energy center's original operating license through 2024. (l) Losses related to reacquired debt. These amounts are being amortized over the lives of the related new debt issuances or the original lives of the old debt issuances if no new debt was issued. (m) The recoverable portion of accrued environmental site liabilities that will be collected from electric and natural gas customers through ICC-approved cost recovery riders. The period of recovery will depend on the timing of remediation expenditures. See Note 15 – Commitments and Contingencies for additional information. (n) Storm costs from 2013 and 2015 deferred in accordance with the IEIMA. These costs are being amortized over five-year periods beginning in 2013 and 2015, respectively. (o) Demand-side costs incurred prior to implementation of the MEEIA in 2013, including the costs of developing, implementing, and evaluating customer energy efficiency and demand response programs. Costs incurred from May 2008 through September 2008 are being amortized over a 10-year period that began in March 2009. Costs incurred from October 2008 through December 2009 are being amortized until May 2017. Costs incurred from January 2010 through February 2011 are being amortized over a six-year period that began in August 2011. Costs incurred from March 2011 through July 2012 are being amortized over a six-year period that began in January 2013. Costs incurred from August 2012 through December 2012 are being amortized over a six-year period that began in June 2015. (p) The period of recovery will depend on the timing of actual expenditures. (q) Ameren Missouri’s costs incurred to enter into and maintain the Missouri Credit Agreement. Additional costs were incurred in December 2014 to amend and restate the Missouri Credit Agreement. These costs are being amortized over the life of the credit facility, ending in December 2019, to construction work in progress, which will be depreciated when assets are placed into service. (r) The MoPSC’s May 2010 electric rate order allowed Ameren Missouri to record an allowance for funds used during construction for pollution control equipment at its Sioux energy center until the cost of that equipment was included in customer rates beginning in 2011. These costs are being amortized over the expected life of the Sioux energy center, which is currently through 2033. (s) Costs associated with Ameren Missouri's solar rebate program beginning in August 2012 to fulfill its renewable energy portfolio requirement. These costs are being amortized over three years, beginning in June 2015. (t) Estimated refunds to transmission customers related to FERC orders. See Ameren Illinois Electric Transmission Rate Refund and FERC Complaint Cases above. (u) Unamortized portion of investment tax credits and reductions to deferred tax liabilities recorded at rates in excess of current statutory rates. The unamortized portion of investment tax credits and the reduction to deferred tax liabilities are being amortized over the expected life of the underlying assets. (v) The tracker is amortized over three years, beginning from the date the amounts are included in rates. See Note 13 – Income Taxes for additional information. (w) Estimated funds collected for the eventual dismantling and removal of plant from service, net of salvage value, upon retirement related to our rate-regulated operations. (x) A regulatory tracking mechanism for the difference between the level of bad debt incurred by Ameren Illinois under GAAP and the level of such costs included in electric and natural gas rates. The over-recovery relating to 2013 was refunded to customers from June 2014 through May 2015. The over-recovery relating to 2014 will be refunded to customers from June 2015 through May 2016. The over-recovery relating to 2015 will be refunded to customers from June 2016 through May 2017. (y) A regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over three to five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. (z) The Ameren Missouri balance includes the costs of renewable energy credits to fulfill Ameren Missouri's renewable energy portfolio requirement from August 2012 through December 2013, which were less than the amount included in rates. These costs are being amortized over three years beginning in June 2015. The Ameren Illinois balance includes funds collected from customers for the purchase of renewable energy credits through IPA procurements for distributed generation. The balance will be amortized as renewable energy credits are purchased. (aa) A regulatory tracking mechanism at Ameren Missouri for the difference between the level of storm costs incurred in a particular year and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. The April 2015 MoPSC order did not approve the continued use of the regulatory tracking mechanisms for storm costs. Ameren, Ameren Missouri, and Ameren Illinois continually assess the recoverability of their regulatory assets. Under current accounting standards, regulatory assets are charged to earnings when it is no longer probable that such amounts will be recovered through future revenues. To the extent that payments of regulatory liabilities are no longer probable, the amounts are credited to earnings. |
Property And Plant, Net
Property And Plant, Net | 12 Months Ended |
Dec. 31, 2015 | |
Property, Plant and Equipment [Abstract] | |
PROPERTY AND PLANT, NET | PROPERTY AND PLANT, NET The following table presents property and plant, net, for each of the Ameren Companies at December 31, 2015 and 2014 : Ameren Missouri (a) Ameren Illinois Other Ameren (a) 2015 Property and plant, at original cost: Electric $ 17,521 $ 7,253 $ 387 $ 25,161 Natural gas 445 1,997 — 2,442 17,966 9,250 387 27,603 Less: Accumulated depreciation and amortization 7,460 2,632 255 10,347 10,506 6,618 132 17,256 Construction work in progress: Nuclear fuel in process 275 — — 275 Other 402 230 636 1,268 Property and plant, net $ 11,183 $ 6,848 $ 768 $ 18,799 2014 Property and plant, at original cost: Electric $ 17,052 $ 6,517 $ 344 $ 23,913 Natural gas 431 1,854 — 2,285 17,483 8,371 344 26,198 Less: Accumulated depreciation and amortization 7,086 2,422 251 9,759 10,397 5,949 93 16,439 Construction work in progress: Nuclear fuel in process 209 — — 209 Other 261 216 299 776 Property and plant, net $ 10,867 $ 6,165 $ 392 $ 17,424 (a) Amounts in Ameren and Ameren Missouri include two CTs under separate capital lease agreements. The gross cumulative asset value of those agreements was $233 million at December 31, 2015 and 2014. The total accumulated depreciation associated with the two CTs was $72 million and $66 million at December 31, 2015 and 2014 , respectively. In addition, Ameren Missouri has investments in debt securities, which were classified as held-to-maturity and recorded in "Other assets", related to the two CTs from the city of Bowling Green and Audrain County. As of December 31, 2015 and 2014, the carrying value of these debt securities was $288 million and $294 million , respectively. The following table provides accrued capital and nuclear fuel expenditures at December 31, 2015 , 2014 , and 2013 , which represent noncash investing activity excluded from the accompanying statements of cash flows: Ameren (a) Ameren Missouri Ameren Illinois Accrued capital expenditures: 2015 $ 235 $ 85 $ 92 2014 181 72 59 2013 175 74 86 Accrued nuclear fuel expenditures: 2015 16 16 (b) 2014 13 13 (b) 2013 8 8 (b) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) Not applicable. |
Short-Term Debt And Liquidity
Short-Term Debt And Liquidity | 12 Months Ended |
Dec. 31, 2015 | |
Line of Credit Facility [Abstract] | |
SHORT-TERM DEBT AND LIQUIDITY | SHORT-TERM DEBT AND LIQUIDITY The liquidity needs of the Ameren Companies are typically supported through the use of available cash, drawings under committed credit agreements, commercial paper issuances, or in the case of Ameren Missouri and Ameren Illinois, short-term intercompany borrowings. Credit Agreements The Credit Agreements provide a total of $2.1 billion of credit through their December 2019 maturity date. The facilities include 24 international, national, and regional lenders, with no single lender providing more than $115 million of credit in aggregate. The obligations of each borrower under the respective Credit Agreements to which it is a party are several and not joint. Except under limited circumstances relating to expenses and indemnities, the obligations of Ameren Missouri and Ameren Illinois under the respective Credit Agreements are not guaranteed by Ameren or any other subsidiary of Ameren. The following table presents the maximum aggregate amount available to each borrower under each facility which will expire in December 2019 (the amount being each borrower's "Borrowing Sublimit"): Missouri Credit Agreement Illinois Credit Agreement Ameren $ 700 $ 500 Ameren Missouri 800 (a) Ameren Illinois (a) 800 (a) Not applicable. Ameren has the option to seek additional commitments from existing or new lenders to increase the total facility size of the Credit Agreements to a maximum of $1.2 billion for the Missouri Credit Agreement and $1.3 billion for the Illinois Credit Agreement. The principal amount of each revolving loan owed by a borrower under any of the Credit Agreements to which it is a party will be due and payable no later than the maturity date of such Credit Agreement. The principal amount of each revolving loan owed by Ameren Missouri or Ameren Illinois under the applicable Credit Agreement will be due and payable no later than the earlier of the maturity date or 364 days after the date of such loan. The Credit Agreements are currently scheduled to mature in December 2019, but the maturity date may be extended once or twice for additional one-year periods upon mutual consent of the borrowers and lenders. The obligations of all borrowers under the Credit Agreements are unsecured. Loans are available on a revolving basis under each of the Credit Agreements. Funds borrowed may be repaid and, subject to satisfaction of the conditions to borrowing, reborrowed from time to time. At the election of each borrower, the interest rates on such loans will be the alternate base rate plus the margin applicable to the particular borrower and/or the eurodollar rate plus the margin applicable to the particular borrower. The applicable margins will be determined by the borrower's long-term unsecured credit ratings or, if no such ratings are in effect, the borrower's corporate/issuer ratings then in effect. The borrowers have received commitments from the lenders to issue letters of credit up to $ 100 million under each of the Credit Agreements. In addition, the issuance of letters of credit is subject to the $2.1 billion overall combined facility borrowing limitations of the Credit Agreements. The borrowers will use the proceeds from any borrowings under the Credit Agreements for general corporate purposes, including working capital, commercial paper liquidity support, issuance of letters of credit, loan funding under the Ameren money pool arrangements, and other short-term intercompany loan arrangements, or for paying fees and expenses incurred in connection with the Credit Agreements. Both of the Credit Agreements are available to Ameren to support issuances under Ameren's commercial paper program, subject to borrowing sublimits. The Missouri Credit Agreement and the Illinois Credit Agreement are available to support issuances under Ameren (parent)'s, Ameren Missouri's and Ameren Illinois' commercial paper programs, respectively. As of December 31, 2015 , based on commercial paper outstanding and letters of credit issued under the Credit Agreements, the aggregate amount of credit capacity available to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, was $1.8 billion . Ameren, Ameren Missouri, and Ameren Illinois did not borrow under the Credit Agreements for the years ended December 31, 2015 and 2014 . Commercial Paper The following table summarizes the borrowing activity and relevant interest rates under Ameren (parent)'s, Ameren Missouri's and Ameren Illinois' commercial paper programs, for the years ended December 31, 2015 and 2014 : Ameren (parent) Ameren Missouri Ameren Illinois Ameren Consolidated 2015 Average daily commercial paper outstanding $ 721 $ 42 $ 4 $ 767 Outstanding borrowings at period-end 301 — — 301 Weighted-average interest rate 0.57 % 0.50 % 0.44 % 0.55 % Peak commercial paper during period (a) $ 874 $ 294 $ 48 $ 1,108 Peak interest rate 0.91 % 0.60 % 0.60 % 0.91 % 2014 Average daily commercial paper outstanding $ 423 $ 110 $ 165 $ 639 Outstanding borrowings at period-end 585 97 32 714 Weighted-average interest rate 0.36 % 0.38 % 0.32 % 0.36 % Peak commercial paper during period (a) $ 625 $ 495 $ 300 $ 910 Peak interest rate 0.75 % 0.70 % 0.60 % 0.75 % (a) The timing of peak commercial paper issuances varies by company, and therefore the peak amounts presented by company might not equal the Ameren Consolidated peak commercial paper issuances for the period. Indebtedness Provisions and Other Covenants The information below is a summary of the Ameren Companies’ compliance with indebtedness provisions and other covenants. The Credit Agreements contain conditions for borrowings and issuances of letters of credit. These include the absence of default or unmatured default, material accuracy of representations and warranties (excluding any representation after the closing date as to the absence of material adverse change and material litigation, and the absence of any notice of violation, liability, or requirement under any environmental laws that could have a material adverse effect), and obtainment of required regulatory authorizations. In addition, it is a condition for any Ameren Illinois borrowing that, at the time of and after giving effect to such borrowing, Ameren Illinois not be in violation of any limitation on its ability to incur unsecured indebtedness contained in its articles of incorporation. The Credit Agreements also contain nonfinancial covenants, including restrictions on the ability to incur liens, to transact with affiliates, to dispose of assets, to make investments in or transfer assets to its affiliates, and to merge with other entities. The Credit Agreements require each of Ameren, Ameren Missouri, and Ameren Illinois to maintain consolidated indebtedness of not more than 65% of its consolidated total capitalization pursuant to a defined calculation set forth in the agreements. As of December 31, 2015 , the ratios of consolidated indebtedness to total consolidated capitalization, calculated in accordance with the provisions of the Credit Agreements, were 51% , 49% , and 47% , for Ameren, Ameren Missouri, and Ameren Illinois, respectively. In addition, under the Illinois Credit Agreement and, by virtue of the cross-default provisions of the Missouri Credit Agreement, under the Missouri Credit Agreement, Ameren is required to maintain a ratio of consolidated funds from operations plus interest expense to consolidated interest expense of 2.0 to 1.0 . However, the interest coverage requirement applies only at such times as Ameren does not have a senior long-term unsecured credit rating of at least Baa3 from Moody's or BBB- from S&P. As of December 31, 2015 , Ameren exceeded the rating requirements; therefore, the interest coverage requirement was not applicable. Any failure by a borrower to satisfy a financial covenant constitutes an immediate default under the applicable Credit Agreement. The Credit Agreements contain default provisions that apply separately to each borrower; provided, however, that a default of Ameren Missouri or Ameren Illinois under the applicable Credit Agreement is also deemed to constitute a default of Ameren under such agreement. Defaults include a cross-default resulting from a default of such borrower under any other agreement covering outstanding indebtedness of such borrower and certain subsidiaries (other than project finance subsidiaries and nonmaterial subsidiaries) in excess of $75 million in the aggregate (including under the other Credit Agreement). However, under the default provisions of the Credit Agreements, any default of Ameren under any Credit Agreement that results solely from a default of Ameren Missouri or Ameren Illinois thereunder does not result in a cross-default of Ameren under the other Credit Agreement. Further, the Credit Agreement default provisions provide that an Ameren default under any of the Credit Agreements does not constitute a default by Ameren Missouri or Ameren Illinois. None of the Ameren Companies' credit agreements or financing agreements contain credit rating triggers that would cause a default or acceleration of repayment of outstanding balances. The Ameren Companies were in compliance with the provisions and covenants of their credit agreements at December 31, 2015 . Money Pools Ameren has money pool agreements with and among its subsidiaries to coordinate and provide for certain short-term cash and working capital requirements. Ameren Missouri, Ameren Illinois, and ATXI may participate in the utility money pool as both lenders and borrowers. Ameren and Ameren Services may participate in the utility money pool only as lenders. Surplus internal funds are contributed to the money pool from participants. The primary sources of external funds for the utility money pool are the Credit Agreements and the commercial paper programs. The total amount available to the pool participants from the utility money pool at any given time is reduced by the amount of borrowings made by participants, but it is increased to the extent that the pool participants advance surplus funds to the utility money pool or remit funds from other external sources. The availability of funds is also determined by funding requirement limits established by regulatory authorizations. Participants receiving a loan under the money pool agreement must repay the principal amount of such loan, together with accrued interest. The rate of interest depends on the composition of internal and external funds in the utility money pool. The average interest rate for borrowing under the money pool for the year ended December 31, 2015 , was 0.11% ( 2014 – 0.19% ). See Note 14 – Related Party Transactions for the amount of interest income and expense from the money pool arrangements recorded by the Ameren Companies for the years ended December 31, 2015 , 2014 , and 2013 . |
Long-Term Debt And Equity Finan
Long-Term Debt And Equity Financings | 12 Months Ended |
Dec. 31, 2015 | |
Long-Term Debt And Equity Financings [Abstract] | |
LONG-TERM DEBT AND EQUITY FINANCINGS | 2.0 3.8 $ 3,385 > 2.5 104.0 $ 2,315 Ameren Illinois > 2.0 6.3 3,566 (d) > 1.5 2.6 203 (e) (a) Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. (b) Amount of bonds issuable based either on required coverage ratios or unfunded property additions, whichever is more restrictive. The amounts shown also include bonds issuable based on retired bond capacity of $946 million and $204 million at Ameren Missouri and Ameren Illinois, respectively. (c) Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. (d) Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. The amount of bonds issuable by Ameren Illinois is also subject to the lien restrictions contained in the Illinois Credit Agreement. (e) Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinois' articles of incorporation. Ameren's indenture does not require Ameren to comply with any quantitative financial covenants. The indenture does, however, include certain cross-default provisions. Specifically, either (1) the failure by Ameren to pay when due and upon expiration of any applicable grace period any portion of any Ameren indebtedness in excess of $25 million , or (2) the acceleration upon default of the maturity of any Ameren indebtedness in excess of $25 million under any indebtedness agreement, including borrowings under the Credit Agreements or the Ameren commercial paper program, constitutes a default under the indenture, unless such past due or accelerated debt is discharged or the acceleration is rescinded or annulled within a specified period. Ameren Missouri and Ameren Illinois and certain other nonregistrant Ameren subsidiaries are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for any officer or director of a public utility, as defined in the Federal Power Act, to participate in the making or paying of any dividend from any funds “properly included in capital account.” The FERC has consistently interpreted the provision to allow dividends to be paid as long as (1) the source of the dividends is clearly disclosed, (2) the dividends are not excessive, and (3) there is no self-dealing on the part of corporate officials. At a minimum, Ameren believes that dividends can be paid by its subsidiaries that are public utilities from net income and retained earnings. In addition, under Illinois law, Ameren Illinois may not pay any dividend on its stock unless, among other things, its earnings and earned surplus are sufficient to declare and pay a dividend after provision is made for reasonable and proper reserves, or unless Ameren Illinois has specific authorization from the ICC. Ameren Illinois’ articles of incorporation require dividend payments on its common stock to be based on ratios of common stock to total capitalization and other provisions related to certain operating expenses and accumulations of earned surplus. Ameren Illinois has made a commitment to the FERC to maintain a minimum 30% ratio of common stock equity to total capitalization. As of December 31, 2015 , Ameren Illinois’ ratio of common stock equity to total capitalization was 51% . In order for the Ameren Companies to issue securities in the future, they will have to comply with all applicable requirements in effect at the time of any such issuances. Off-Balance-Sheet Arrangements At December 31, 2015 , none of the Ameren Companies had off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business, letters of credit, and Ameren parent guarantee arrangements on behalf of its subsidiaries. None of the Ameren Companies expect to engage in any significant off-balance-sheet financing arrangements in the near future." id="sjs-B4">LONG-TERM DEBT AND EQUITY FINANCINGS The following table presents long-term debt outstanding, including maturities due within one year, for the Ameren Companies as of December 31, 2015 and 2014 : 2015 2014 Ameren (Parent): 2.70% Senior unsecured notes due 2020 $ 350 $ — 3.65% Senior unsecured notes due 2026 350 — Total long-term debt, gross 700 — Less: Unamortized debt issuance costs (a) (6 ) — Long-term debt, net $ 694 $ — Ameren Missouri: Senior secured notes: (b) 4.75% Senior secured notes due 2015 — 114 5.40% Senior secured notes due 2016 260 260 6.40% Senior secured notes due 2017 425 425 6.00% Senior secured notes due 2018 (c) 179 179 5.10% Senior secured notes due 2018 199 199 6.70% Senior secured notes due 2019 (c) 329 329 5.10% Senior secured notes due 2019 244 244 5.00% Senior secured notes due 2020 85 85 3.50% Senior secured notes due 2024 350 350 5.50% Senior secured notes due 2034 184 184 5.30% Senior secured notes due 2037 300 300 8.45% Senior secured notes due 2039 (c) 350 350 3.90% Senior secured notes due 2042 (c) 485 485 3.65% Senior secured notes due 2045 250 — Environmental improvement and pollution control revenue bonds: 1992 Series due 2022 (d)(e) 47 47 1993 5.45% Series due 2028 (f) (f) (f) 1998 Series A due 2033 (d)(e) 60 60 1998 Series B due 2033 (d)(e) 50 50 1998 Series C due 2033 (d)(e) 50 50 Capital lease obligations: City of Bowling Green capital lease (Peno Creek CT) due 2022 48 54 Audrain County capital lease (Audrain County CT) due 2023 240 240 Total long-term debt, gross 4,135 4,005 Less: Unamortized discount and premium (6 ) (6 ) Less: Unamortized debt issuance costs (a) (19 ) (18 ) Less: Maturities due within one year (266 ) (120 ) Long-term debt, net $ 3,844 $ 3,861 2015 2014 Ameren Illinois: Senior secured notes: 6.20% Senior secured notes due 2016 (g) $ 54 $ 54 6.25% Senior secured notes due 2016 (h) 75 75 6.125% Senior secured notes due 2017 (h)(i) 250 250 6.25% Senior secured notes due 2018 (h)(i) 144 144 9.75% Senior secured notes due 2018 (h)(i) 313 313 2.70% Senior secured notes due 2022 (h)(i) 400 400 3.25% Senior secured notes due 2025 (h) 300 300 6.125% Senior secured notes due 2028 (h) 60 60 6.70% Senior secured notes due 2036 (h) 61 61 6.70% Senior secured notes due 2036 (g) 42 42 4.80% Senior secured notes due 2043 (h) 280 280 4.30% Senior secured notes due 2044 (h) 250 250 4.15% Senior secured notes due 2046 (h) 250 — Environmental improvement and pollution control revenue bonds: 5.90% Series 1993 due 2023 (j) (j) (j) 5.70% 1994A Series due 2024 (k) (k) (k) 1993 Series B-1 due 2028 (e)(l) 17 17 Total long-term debt, gross 2,496 2,246 Less: Unamortized discount and premium (7 ) (5 ) Less: Unamortized debt issuance costs (a) (18 ) (17 ) Less: Maturities due within one year (129 ) — Long-term debt, net $ 2,342 $ 2,224 Ameren consolidated long-term debt, net $ 6,880 $ 6,085 (a) Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies for additional information. (b) These notes are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under the Ameren Missouri mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Missouri senior secured notes currently outstanding, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2042. (c) Ameren Missouri has agreed that so long as any of the 3.90% senior secured notes due 2042 are outstanding, Ameren Missouri will not permit a release date to occur, and so long as any of the 6.70% senior secured notes due 2019, 6.00% senior secured notes due 2018 and 8.45% senior secured notes due 2039 are outstanding, Ameren Missouri will not optionally redeem, purchase, or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions. (d) These bonds are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture and have a fall-away lien provision similar to that of Ameren Missouri's senior secured notes. The bonds are also backed by an insurance guarantee policy. (e) The interest rates, and the periods during which such rates apply, vary depending on our selection of defined rate modes. Maximum interest rates could reach 18% depending on the series of bonds. The bonds are callable at 100% of par value. The average interest rates for 2015 and 2014 were as follows: 2015 2014 Ameren Missouri 1992 Series due 2022 0.06% 0.10% Ameren Missouri 1998 Series A due 2033 0.24% 0.26% Ameren Missouri 1998 Series B due 2033 0.24% 0.27% Ameren Missouri 1998 Series C due 2033 0.24% 0.26% Ameren Illinois 1993 Series B-1 due 2028 0.49% 0.21% (f) These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. (g) These notes are collaterally secured by first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. The notes have a fall-away lien provision, and Ameren Illinois could cause these notes to become unsecured at any time by redeeming the pollution control bonds 5.90% Series 1993 due 2023 (of which less than $1 million remains outstanding). (h) These notes are collaterally secured by mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois senior secured notes currently outstanding, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2024. (i) Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur, and so long as any of the 9.75% senior secured notes due 2018, 6.25% senior secured notes due 2018 and 6.125% senior secured notes due 2017 are outstanding, Ameren Illinois will not optionally redeem, purchase or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions; therefore, a release date will not occur so long as any of these notes remain outstanding. (j) These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. They are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. (k) These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. Less than $1 million principal amount of the bonds remains outstanding. (l) The bonds are callable at 100% of par value. The following table presents the aggregate maturities of long-term debt, including current maturities, for the Ameren Companies at December 31, 2015 : Ameren (parent) (a) Ameren Missouri (a) Ameren Illinois (a) Ameren Consolidated 2016 $ — $ 266 $ 129 $ 395 2017 — 431 250 681 2018 — 383 457 840 2019 — 581 — 581 2020 350 92 — 442 Thereafter 350 2,382 1,660 4,392 Total $ 700 $ 4,135 $ 2,496 $ 7,331 (a) Excludes unamortized discount and premium and debt issuance costs of $6 million , $25 million , and $25 million at Ameren (parent), Ameren Missouri, and Ameren Illinois, respectively. All classes of Ameren Missouri’s and Ameren Illinois’ preferred stock are entitled to cumulative dividends, have voting rights, and are not subject to mandatory redemption. The preferred stock of Ameren's subsidiaries was included in "Noncontrolling Interests" on Ameren's consolidated balance sheet. The following table presents the outstanding preferred stock of Ameren Missouri and Ameren Illinois, which is redeemable, at the option of the issuer, at the prices shown below as of December 31, 2015 and 2014 : Redemption Price(per share) 2015 2014 Ameren Missouri: Without par value and stated value of $100 per share, 25 million shares authorized $3.50 Series 130,000 shares $ 110.00 $ 13 $ 13 $3.70 Series 40,000 shares 104.75 4 4 $4.00 Series 150,000 shares 105.625 15 15 $4.30 Series 40,000 shares 105.00 4 4 $4.50 Series 213,595 shares 110.00 (a) 21 21 $4.56 Series 200,000 shares 102.47 20 20 $4.75 Series 20,000 shares 102.176 2 2 $5.50 Series A 14,000 shares 110.00 1 1 Total $ 80 $ 80 Ameren Illinois: With par value of $100 per share, 2 million shares authorized 4.00% Series 144,275 shares $ 101.00 $ 14 $ 14 4.08% Series 45,224 shares 103.00 5 5 4.20% Series 23,655 shares 104.00 2 2 4.25% Series 50,000 shares 102.00 5 5 4.26% Series 16,621 shares 103.00 2 2 4.42% Series 16,190 shares 103.00 2 2 4.70% Series 18,429 shares 103.00 2 2 4.90% Series 73,825 shares 102.00 7 7 4.92% Series 49,289 shares 103.50 5 5 5.16% Series 50,000 shares 102.00 5 5 6.625% Series 124,274 shares 100.00 12 12 7.75% Series 4,542 shares 100.00 1 1 Total $ 62 $ 62 Total Ameren $ 142 $ 142 (a) In the event of voluntary liquidation, $105.50 . Ameren has 100 million shares of $0.01 par value preferred stock authorized, with no such shares outstanding. Ameren Missouri has 7.5 million shares of $1 par value preference stock authorized, with no such shares outstanding. Ameren Illinois has 2.6 million shares of no par value preferred stock authorized, with no such shares outstanding. Ameren In November 2015, Ameren (parent) issued $350 million of 2.70% senior unsecured notes due November 15, 2020, with interest payable semiannually on May 15 and November 15 of each year, beginning May 15, 2016. Ameren (parent) received proceeds of $348 million , which were used to repay a portion of short-term debt. In November 2015, Ameren (parent) issued $350 million of 3.65% senior unsecured notes due February 15, 2026, with interest payable semiannually on February 15 and August 15 of each year, beginning February 15, 2016. Ameren (parent) received proceeds of $347 million , which were used to repay a portion of short-term debt. In May 2014, Ameren (parent) repaid at maturity $425 million of its 8.875% senior unsecured notes, plus accrued interest. The notes were repaid with proceeds from commercial paper issuances. In June 2015, Ameren, Ameren Missouri, and Ameren Illinois filed a Form S-3 shelf registration statement registering the issuance of an indeterminate amount of certain types of securities. The registration statement became effective immediately upon filing and will expire in June 2018. Ameren filed a Form S-3 registration statement with the SEC in May 2014, authorizing the offering of 8.6 million additional shares of its common stock under DRPlus, which expires in May 2017. Shares of common stock sold under DRPlus are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. In October 2013, Ameren filed a Form S-8 registration statement with the SEC, authorizing the offering of 4 million additional shares of its common stock under its 401(k) plan. Shares of common stock sold under the 401(k) plan are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. From 2013 through 2015, Ameren shares for its DRPlus and its 401(k) plans were purchased in the open market. Ameren Missouri In February 2016, $260 million principal amount of Ameren Missouri's 5.40% senior secured notes matured and were repaid with cash on hand and commercial paper borrowings. In April 2015, Ameren Missouri issued $250 million of 3.65% senior secured notes due April 15, 2045, with interest payable semiannually on April 15 and October 15 of each year, beginning October 15, 2015. Ameren Missouri received proceeds of $247 million , which were used to repay outstanding short-term debt, including short-term debt that Ameren Missouri incurred in connection with the repayment of $114 million of its 4.75% senior secured notes that matured on April 1, 2015. In April 2014, Ameren Missouri issued $350 million of 3.50% senior secured notes due April 15, 2024, with interest payable semiannually on April 15 and October 15 of each year, beginning October 15, 2014. Ameren Missouri received proceeds of $348 million , which were used to repay at maturity $104 million of its 5.50% senior secured notes due May 15, 2014 and to repay a portion of its short-term debt. For information on Ameren Missouri's capital contributions and return of capital, refer to Capital Contributions and Return of Capital in Note 1 – Summary of Significant Accounting Policies. Ameren Illinois In December 2015, Ameren Illinois issued $250 million of 4.15% senior secured notes due March 15, 2046, with interest payable semiannually on March 15 and September 15, beginning March 15, 2016. Ameren Illinois received proceeds of $245 million , which were used to repay a portion of its short-term debt. In January 2014, Ameren Illinois redeemed the following environmental improvement and pollution control revenue bonds at par value plus accrued interest: Senior Secured Notes Principal Amount 5.90% Series 1993 due 2023 (a) $ 32 5.70% 1994A Series due 2024 (a) 36 1993 Series C-1 5.95% due 2026 35 1993 Series C-2 5.70% due 2026 8 5.40% 1998A Series due 2028 19 5.40% 1998B Series due 2028 33 Total amount redeemed $ 163 (a) Less than $1 million principal amount of the bonds remains outstanding after redemption. In June 2014, Ameren Illinois issued $250 million of 4.30% senior secured notes due July 1, 2044, with interest payable semiannually on January 1 and July 1, beginning January 1, 2015. Ameren Illinois received proceeds of $246 million , which were used to repay a portion of its short-term debt. In December 2014, Ameren Illinois issued $300 million of 3.25% senior secured notes due March 1, 2025, with interest payable semiannually on March 1 and September 1, beginning March 1, 2015. Ameren Illinois received proceeds of $298 million , which were used to repay a portion of its short-term debt. For information on Ameren Illinois' capital contributions, refer to Capital Contributions and Return of Capital in Note 1 – Summary of Significant Accounting Policies. Indenture Provisions and Other Covenants Ameren Missouri’s and Ameren Illinois’ indentures, credit facilities, and articles of incorporation include covenants and provisions related to issuances of first mortgage bonds and preferred stock. Ameren Missouri and Ameren Illinois are required to meet certain ratios to issue additional first mortgage bonds and preferred stock. A failure to achieve these ratios would not result in a default under these covenants and provisions but would restrict the companies’ ability to issue bonds or preferred stock. The following table summarizes the required and actual interest coverage ratios for interest charges, dividend coverage ratios, and bonds and preferred stock issuable as of December 31, 2015 , at an assumed interest rate of 5% and dividend rate of 6% . Required Interest Coverage Ratio (a) Actual Interest Coverage Ratio Bonds Issuable (b) Required Dividend Coverage Ratio (c) Actual Dividend Coverage Ratio Preferred Stock Issuable Ameren Missouri > 2.0 3.8 $ 3,385 > 2.5 104.0 $ 2,315 Ameren Illinois > 2.0 6.3 3,566 (d) > 1.5 2.6 203 (e) (a) Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. (b) Amount of bonds issuable based either on required coverage ratios or unfunded property additions, whichever is more restrictive. The amounts shown also include bonds issuable based on retired bond capacity of $946 million and $204 million at Ameren Missouri and Ameren Illinois, respectively. (c) Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. (d) Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. The amount of bonds issuable by Ameren Illinois is also subject to the lien restrictions contained in the Illinois Credit Agreement. (e) Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinois' articles of incorporation. Ameren's indenture does not require Ameren to comply with any quantitative financial covenants. The indenture does, however, include certain cross-default provisions. Specifically, either (1) the failure by Ameren to pay when due and upon expiration of any applicable grace period any portion of any Ameren indebtedness in excess of $25 million , or (2) the acceleration upon default of the maturity of any Ameren indebtedness in excess of $25 million under any indebtedness agreement, including borrowings under the Credit Agreements or the Ameren commercial paper program, constitutes a default under the indenture, unless such past due or accelerated debt is discharged or the acceleration is rescinded or annulled within a specified period. Ameren Missouri and Ameren Illinois and certain other nonregistrant Ameren subsidiaries are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for any officer or director of a public utility, as defined in the Federal Power Act, to participate in the making or paying of any dividend from any funds “properly included in capital account.” The FERC has consistently interpreted the provision to allow dividends to be paid as long as (1) the source of the dividends is clearly disclosed, (2) the dividends are not excessive, and (3) there is no self-dealing on the part of corporate officials. At a minimum, Ameren believes that dividends can be paid by its subsidiaries that are public utilities from net income and retained earnings. In addition, under Illinois law, Ameren Illinois may not pay any dividend on its stock unless, among other things, its earnings and earned surplus are sufficient to declare and pay a dividend after provision is made for reasonable and proper reserves, or unless Ameren Illinois has specific authorization from the ICC. Ameren Illinois’ articles of incorporation require dividend payments on its common stock to be based on ratios of common stock to total capitalization and other provisions related to certain operating expenses and accumulations of earned surplus. Ameren Illinois has made a commitment to the FERC to maintain a minimum 30% ratio of common stock equity to total capitalization. As of December 31, 2015 , Ameren Illinois’ ratio of common stock equity to total capitalization was 51% . In order for the Ameren Companies to issue securities in the future, they will have to comply with all applicable requirements in effect at the time of any such issuances. Off-Balance-Sheet Arrangements At December 31, 2015 , none of the Ameren Companies had off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business, letters of credit, and Ameren parent guarantee arrangements on behalf of its subsidiaries. None of the Ameren Companies expect to engage in any significant off-balance-sheet financing arrangements in the near future. |
Other Income And Expenses
Other Income And Expenses | 12 Months Ended |
Dec. 31, 2015 | |
Other Nonoperating Income (Expense) [Abstract] | |
OTHER INCOME AND EXPENSES | OTHER INCOME AND EXPENSES The following table presents the components of "Other Income and Expenses" in the Ameren Companies’ statements of income (loss) for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren: (a) Miscellaneous income: Allowance for equity funds used during construction $ 30 $ 34 $ 37 Interest income on industrial development revenue bonds 27 27 27 Interest income (b) 14 10 3 Other 3 8 (c) 2 Total miscellaneous income $ 74 $ 79 $ 69 Miscellaneous expense: Donations $ 15 $ 10 $ 12 Other 15 12 14 Total miscellaneous expense $ 30 $ 22 $ 26 Ameren Missouri: Miscellaneous income: Allowance for equity funds used during construction $ 22 $ 32 $ 31 Interest income on industrial development revenue bonds 27 27 27 Interest income 1 1 — Other 2 — — Total miscellaneous income $ 52 $ 60 $ 58 Miscellaneous expense: Donations $ 5 $ 6 $ 4 Other 6 6 7 Total miscellaneous expense $ 11 $ 12 $ 11 Ameren Illinois: Miscellaneous income: Allowance for equity funds used during construction $ 8 $ 2 $ 6 Interest income (b) 12 7 2 Other 1 8 (c) 2 Total miscellaneous income $ 21 $ 17 $ 10 Miscellaneous expense: Donations $ 5 $ 4 $ 4 Other 7 4 5 Total miscellaneous expense $ 12 $ 8 $ 9 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (b) Includes Ameren Illinois' interest income on the IEIMA revenue requirement reconciliation adjustment regulatory assets. (c) Includes Ameren Illinois' income earned in 2014 from customer-requested construction. |
Derivative Financial Instrument
Derivative Financial Instruments | 12 Months Ended |
Dec. 31, 2015 | |
Derivative Instrument Detail [Abstract] | |
DERIVATIVE FINANCIAL INSTRUMENTS | DERIVATIVE FINANCIAL INSTRUMENTS We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following: • an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices; • market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; and • actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays. The derivatives that we use to hedge these risks are governed by our risk management policies for forward contracts, futures, options, and swaps. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. The goal of the hedging program is generally to mitigate financial risks while ensuring that sufficient volumes are available to meet our requirements. Contracts we enter into as part of our risk management program may be settled financially, settled by physical delivery, or net settled with the counterparty. The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of December 31, 2015 and 2014 . As of December 31, 2015 , these contracts ran through October 2018, March 2021, May 2032, and January 2019 for fuel oils, natural gas, power, and uranium, respectively. Quantity (in millions, except as indicated) 2015 2014 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) (a) 35 (b) 35 50 (b) 50 Natural gas (in mmbtu) 30 151 181 28 108 136 Power (in megawatthours) 1 10 11 1 11 12 Uranium (pounds in thousands) 494 (b) 494 332 (b) 332 (a) Fuel oils consist of heating oil and ultra-low-sulfur diesel. (b) Not applicable. Authoritative accounting guidance regarding derivative instruments requires that all contracts considered to be derivative instruments be recorded on the balance sheet at their fair values, unless the NPNS exception applies. See Note 8 – Fair Value Measurements for discussion of our methods of assessing the fair value of derivative instruments. Many of our physical contracts, such as our purchased power contracts, qualify for the NPNS exception to derivative accounting rules. The revenue or expense on NPNS contracts is recognized at the contract price upon physical delivery. If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether it qualifies for hedge accounting. We also consider whether gains or losses resulting from such derivatives qualify for regulatory deferral. Derivative contracts that qualify for regulatory deferral are recorded at fair value, with changes in fair value recorded as regulatory assets or regulatory liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and regulatory liabilities are probable of recovery or refund through future rates charged to customers. Regulatory assets and regulatory liabilities are amortized to operating income as related losses and gains are reflected in rates charged to customers. Therefore, gains and losses on these derivatives have no effect on operating income. As of December 31, 2015 and 2014 , all contracts that qualify for hedge accounting receive regulatory deferral. Authoritative accounting guidance permits companies to offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a liability) against fair value amounts recognized for derivative instruments that are executed with the same counterparty under a master netting arrangement or similar agreement. The Ameren Companies did not elect to adopt this guidance for any eligible derivative instruments. The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of December 31, 2015 and 2014 : Balance Sheet Location Ameren Missouri Ameren Illinois Ameren 2015 Natural gas Other current assets $ — $ 1 $ 1 Other assets 1 — 1 Power Other current assets 16 — 16 Total assets (a) $ 17 $ 1 $ 18 Fuel oils Other current liabilities $ 22 $ — $ 22 Other deferred credits and liabilities 7 — 7 Natural gas MTM derivative liabilities (b) 32 (b) Other current liabilities 6 — 38 Other deferred credits and liabilities 8 18 26 Power MTM derivative liabilities (b) 13 (b) Other current liabilities — — 13 Other deferred credits and liabilities — 157 157 Uranium Other current liabilities 1 — 1 Total liabilities (c) $ 44 $ 220 $ 264 2014 Fuel oils Other current assets $ 2 $ — $ 2 Natural gas Other current assets 1 1 2 Power Other current assets 15 — 15 Total assets (a) $ 18 $ 1 $ 19 Fuel oils Other current liabilities $ 22 $ — $ 22 Other deferred credits and liabilities 7 — 7 Natural gas MTM derivative liabilities (b) 31 (b) Other current liabilities 6 — 37 Other deferred credits and liabilities 6 13 19 Power MTM derivative liabilities (b) 11 (b) Other current liabilities 3 — 14 Other deferred credits and liabilities — 131 131 Uranium Other current liabilities 2 — 2 Total liabilities (c) $ 46 $ 186 $ 232 (a) Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net gains on all derivative instruments is deferred as a regulatory liability. (b) Balance sheet line item not applicable to registrant. (c) Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net losses on all derivative instruments is deferred as a regulatory asset. Derivative instruments are subject to various credit-related losses in the event of nonperformance by counterparties to the transaction. Exchange-traded contracts are supported by the financial and credit quality of the clearing members of the respective exchanges and have nominal credit risk. In all other transactions, we are exposed to credit risk. Our credit risk management program involves establishing credit limits and collateral requirements for counterparties, using master netting arrangements or similar agreements, and reporting daily exposure to senior management. We believe that entering into master netting arrangements or similar agreements mitigates the level of financial loss that could result from default by allowing net settlement of derivative assets and liabilities. We generally enter into the following master netting arrangements: (1) the International Swaps and Derivatives Association Agreement, a standardized financial natural gas and electric contract; (2) the Master Power Purchase and Sale Agreement, created by the Edison Electric Institute and the National Energy Marketers Association, a standardized contract for the purchase and sale of wholesale power; and (3) the North American Energy Standards Board Inc. Agreement, a standardized contract for the purchase and sale of natural gas. These master netting arrangements allow the counterparties to net settle sale and purchase transactions. Further, collateral requirements are calculated at the master netting arrangement or similar agreement level by counterparty. The following table provides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of December 31, 2015 and 2014 : Gross Amounts Not Offset on the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized on the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount 2015 Assets: Ameren Missouri $ 17 $ 1 $ — $ 16 Ameren Illinois 1 — — 1 Ameren $ 18 $ 1 $ — $ 17 Liabilities: Ameren Missouri $ 44 $ 1 $ 8 $ 35 Ameren Illinois 220 — 3 217 Ameren $ 264 $ 1 $ 11 $ 252 2014 Assets: Ameren Missouri $ 18 $ 5 $ — $ 13 Ameren Illinois 1 — — 1 Ameren $ 19 $ 5 $ — $ 14 Liabilities: Ameren Missouri $ 46 $ 5 $ 5 $ 36 Ameren Illinois 186 — — 186 Ameren $ 232 $ 5 $ 5 $ 222 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. Concentrations of Credit Risk In determining our concentrations of credit risk related to derivative instruments, we review our individual counterparties and categorize each counterparty into groupings according to the primary business in which each engages. We calculate maximum exposures based on the gross fair value of financial instruments, including NPNS and other accrual contracts. These exposures are presented on a gross basis, which include affiliate exposure not eliminated at the consolidated Ameren level. The potential loss on counterparty exposures may be reduced or eliminated by the application of master netting arrangements or similar agreements and collateral held. As of December 31, 2015 , if counterparty groups were to fail completely to perform on contracts, Ameren's, Ameren Missouri's, and Ameren Illinois' maximum exposure would have been immaterial with or without consideration of the application of master netting arrangements or similar agreements and collateral held. Derivative Instruments with Credit Risk-Related Contingent Features Our commodity contracts contain collateral provisions tied to the Ameren Companies’ credit ratings. If we were to experience an adverse change in our credit ratings, or if a counterparty with reasonable grounds for uncertainty regarding performance of an obligation requested adequate assurance of performance, additional collateral postings might be required. The following table presents, as of December 31, 2015 , the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require. The additional collateral required is the net liability position allowed under the master netting arrangements or similar agreements assuming (1) the credit risk-related contingent features underlying these arrangements were triggered on December 31, 2015 , and (2) those counterparties with rights to do so requested collateral. Aggregate Fair Value of Derivative Liabilities (a) Cash Collateral Posted Potential Aggregate Amount of Additional Collateral Required (b) 2015 Ameren Missouri $ 87 $ 9 $ 72 Ameren Illinois 78 3 71 Ameren $ 165 $ 12 $ 143 (a) Before consideration of master netting arrangements or similar agreements and including NPNS and other accrual contract exposures. (b) As collateral requirements with certain counterparties are based on master netting arrangements or similar agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such arrangements. |
Fair Value Measurements
Fair Value Measurements | 12 Months Ended |
Dec. 31, 2015 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTS Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. We use various methods to determine fair value, including market, income, and cost approaches. With these approaches, we adopt certain assumptions that market participants would use in pricing the asset or liability, including assumptions about market risk or the risks inherent in the inputs to the valuation. Inputs to valuation can be readily observable, market-corroborated, or unobservable. We use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. Authoritative accounting guidance established a fair value hierarchy that prioritizes the inputs used to measure fair value. All financial assets and liabilities carried at fair value are classified and disclosed in one of the following three hierarchy levels: Level 1 : Inputs based on quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities are primarily exchange-traded derivatives and assets, including cash and cash equivalents and listed equity securities, such as those held in Ameren Missouri’s nuclear decommissioning trust fund. The market approach is used to measure the fair value of equity securities held in Ameren Missouri's nuclear decommissioning trust fund. Equity securities in this fund are representative of the S&P 500 index, excluding securities of Ameren Corporation, owners and/or operators of nuclear power plants, and the trustee and investment managers. The S&P 500 index comprises stocks of large-capitalization companies. Level 2 : Market-based inputs corroborated by third-party brokers or exchanges based on transacted market data. Level 2 assets and liabilities include certain assets held in Ameren Missouri’s nuclear decommissioning trust fund, including corporate bonds and other fixed-income securities, United States Treasury and agency securities, and certain over-the-counter derivative instruments, including natural gas and financial power transactions. Fixed income securities are valued by using prices from independent industry recognized data vendors who provide values that are either exchange-based or matrix-based. The fair value measurements of fixed income securities classified as Level 2 are based on inputs other than quoted prices that are observable for the asset or liability. Examples are matrix pricing, market corroborated pricing, and inputs such as yield curves and indices. Level 2 fixed income securities in the nuclear decommissioning trust fund are primarily corporate bonds, asset-backed securities, and United States agency bonds. Derivative instruments classified as Level 2 are valued by corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets. Our development and corroboration process entails obtaining multiple quotes or prices from outside sources. To derive our forward view to price our derivative instruments at fair value, we average the midpoints of the bid/ask spreads. To validate forward prices obtained from outside parties, we compare the pricing to recently settled market transactions. Additionally, a review of all sources is performed to identify any anomalies or potential errors. Further, we consider the volume of transactions on certain trading platforms in our reasonableness assessment of the averaged midpoint. The value of natural gas derivative contracts is based upon exchange closing prices without significant unobservable adjustments. The value of power derivatives contracts is based upon the use of multiple forward prices provided by third parties. The prices are averaged and shaped to a monthly profile when needed without significant unobservable adjustments. Level 3 : Unobservable inputs that are not corroborated by market data. Level 3 assets and liabilities are valued by internally developed models and assumptions or methodologies that use significant unobservable inputs. Level 3 assets and liabilities include derivative instruments that trade in less liquid markets, where pricing is largely unobservable. We value Level 3 instruments by using pricing models with inputs that are often unobservable in the market, as well as certain internal assumptions. Our development and corroboration process entails obtaining multiple quotes or prices from outside sources. As a part of our reasonableness review, an evaluation of all sources is performed to identify any anomalies or potential errors. We perform an analysis each quarter to determine the appropriate hierarchy level of the assets and liabilities subject to fair value measurements. Financial assets and liabilities are classified in their entirety according to the lowest level of input that is significant to the fair value measurement. All assets and liabilities whose fair value measurement is based on significant unobservable inputs are classified as Level 3. The following table describes the valuation techniques and unobservable inputs utilized by the Ameren Companies for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the periods ended December 31, 2015 and 2014 : Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Level 3 Derivative asset and liability – commodity contracts (a) : 2015 Natural Gas $ 1 $ (1 ) Option model Volatilities(%) (b) 35 – 55 45 Nodal basis($/mmbtu) (c) (0.30) – 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (b) (0.10) – 0 (0.10) Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Counterparty credit risk(%) (c)(d) 0.40 – 12 7 Ameren Missouri credit risk(%) (c)(d) 0.40 (e) Power (f) 16 (170 ) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps($/MWh) (g) 22 – 39 29 Estimated auction price for FTRs($/MW) (b) (270) – 2,057 211 Nodal basis($/MWh) (g) (10) – (1) (3) Counterparty credit risk(%) (c)(d) 0.86 (e) Ameren Illinois credit risk(%) (c)(d) 0.40 (e) Fundamental energy production model Estimated future gas prices($/mmbtu) (b) 3 – 4 4 Escalation rate(%) (b)(h) 3 (e) Contract price allocation Estimated renewable energy credit costs($/credit) (b) 5 – 7 6 Uranium — (1 ) Option model Volatilities(%) (b) 20 (e) Discounted cash flow Average forward uranium pricing($/pound) (b) 35 – 42 37 Ameren Missouri credit risk(%) (c)(d) 0.40 (e) 2014 Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (c) 3 – 39 32 Discounted cash flow Ameren Missouri credit risk(%) (c)(d) 0.43 (e) Escalation rate(%) (b)(i) 5 (e) Natural Gas 1 (2 ) Option model Volatilities(%) (c) 31 – 144 63 Nodal basis($/mmbtu) (b) (0.40) – 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (b) (0.40) – 0.10 (0.20) Counterparty credit risk(%) (c)(d) 0.43 – 13 3 Ameren Missouri and Ameren Illinois credit risk(%) (c)(d) 0.43 (e) Power (f) 11 (144 ) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps($/MWh) (g) 27 – 50 32 Estimated auction price for FTRs($/MW) (b) (1,833) – 2,743 171 Nodal basis($/MWh) (b) (6) – 0 (2) Counterparty credit risk(%) (c)(d) 0.26 (e) Ameren Missouri and Ameren Illinois credit risk(%) (c)(d) 0.43 (e) Fundamental energy production model Estimated future gas prices($/mmbtu) (b) 4 – 5 4 Escalation rate(%) (b)(h) 0 – 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (b) 5 – 7 6 Uranium — (2 ) Discounted cash flow Average forward uranium pricing($/pound) (b) 35 – 40 36 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (c) Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. (d) Counterparty credit risk is applied only to counterparties with derivative asset balances. Ameren Missouri and Ameren Illinois credit risk is applied only to counterparties with derivative liability balances. (e) Not applicable. (f) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2019. Valuations beyond 2019 use fundamentally modeled pricing by month for peak and off-peak demand. (g) The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes because of their opposing positions. (h) Escalation rate applies to power prices 2026 and beyond. (i) Escalation rate applies to fuel oil prices 2017 and beyond. In accordance with applicable authoritative accounting guidance, we consider nonperformance risk in our valuation of derivative instruments by analyzing the credit standing of our counterparties and considering any counterparty credit enhancements (e.g., collateral). The guidance also requires that the fair value measurement of liabilities reflect the nonperformance risk of the reporting entity, as applicable. Therefore, we have factored the impact of our credit standing, as well as any potential credit enhancements, into the fair value measurement of both derivative assets and derivative liabilities. Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in 2015, 2014 or 2013. At December 31, 2015 and 2014 , the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois. The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of December 31, 2015 : Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Assets: Ameren Derivative assets – commodity contracts (a) : Natural gas $ — $ 1 $ 1 $ 2 Power — — 16 16 Total derivative assets – commodity contracts $ — $ 1 $ 17 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 4 $ — $ — $ 4 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 109 — 109 Corporate bonds — 58 — 58 Other — 22 — 22 Total nuclear decommissioning trust fund $ 368 $ 189 $ — $ 557 (b) Total Ameren $ 368 $ 190 $ 17 $ 575 Ameren Missouri Derivative assets – commodity contracts (a) : Natural gas $ — $ — $ 1 $ 1 Power — — 16 16 Total derivative assets – commodity contracts $ — $ — $ 17 $ 17 Nuclear decommissioning trust fund: Cash and cash equivalents $ 4 $ — $ — $ 4 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 109 — 109 Corporate bonds — 58 — 58 Other — 22 — 22 Total nuclear decommissioning trust fund $ 368 $ 189 $ — $ 557 (b) Total Ameren Missouri $ 368 $ 189 $ 17 $ 574 Ameren Illinois Derivative assets – commodity contracts (a) : Natural gas $ — $ 1 $ — $ 1 Liabilities: Ameren Derivative liabilities – commodity contracts (a) : Fuel oils $ 29 $ — $ — $ 29 Natural gas 1 62 1 64 Power — — 170 170 Uranium — — 1 1 Total Ameren $ 30 $ 62 $ 172 $ 264 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Ameren Missouri Derivative liabilities – commodity contracts (a) : Fuel oils $ 29 $ — $ — $ 29 Natural gas — 13 1 14 Power — — — — Uranium — — 1 1 Total Ameren Missouri $ 29 $ 13 $ 2 $ 44 Ameren Illinois Derivative liabilities – commodity contracts (a) : Natural gas $ 1 $ 49 $ — $ 50 Power — — 170 170 Total Ameren Illinois $ 1 $ 49 $ 170 $ 220 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Balance excludes $(1) million of receivables, payables, and accrued income, net. The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 : Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Assets: Ameren Derivative assets – commodity contracts (a) : Fuel oils $ — $ — $ 2 $ 2 Natural gas — 1 1 2 Power — 4 11 15 Total derivative assets – commodity contracts $ — $ 5 $ 14 $ 19 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ — $ — $ 1 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 102 — 102 Corporate bonds — 63 — 63 Other — 17 — 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ — $ 547 (b) Total Ameren $ 365 $ 187 $ 14 $ 566 Ameren Missouri Derivative assets – commodity contracts (a) : Fuel oils $ — $ — $ 2 $ 2 Natural gas — 1 — 1 Power — 4 11 15 Total derivative assets – commodity contracts $ — $ 5 $ 13 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ — $ — $ 1 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 102 — 102 Corporate bonds — 63 — 63 Other — 17 — 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ — $ 547 (b) Total Ameren Missouri $ 365 $ 187 $ 13 $ 565 Ameren Illinois Derivative assets – commodity contracts (a) : Natural gas $ — $ — $ 1 $ 1 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Liabilities: Ameren Derivative liabilities – commodity contracts (a) : Fuel oils $ 21 $ — $ 8 $ 29 Natural gas 1 53 2 56 Power — 1 144 145 Uranium — — 2 2 Total Ameren $ 22 $ 54 $ 156 $ 232 Ameren Missouri Derivative liabilities – commodity contracts (a) : Fuel oils $ 21 $ — $ 8 $ 29 Natural gas 1 10 1 12 Power — 1 2 3 Uranium — — 2 2 Total Ameren Missouri $ 22 $ 11 $ 13 $ 46 Ameren Illinois Derivative liabilities – commodity contracts (a) : Natural gas $ — $ 43 $ 1 $ 44 Power — — 142 142 Total Ameren Illinois $ — $ 43 $ 143 $ 186 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Balance excludes $2 million of receivables, payables, and accrued income, net. The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the year ended December 31, 2015 : Net Derivative Commodity Contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2015 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 5 (a) 5 Transfers out of Level 3 2 (a) 2 Ending balance at December 31, 2015 $ — $ (a) $ — Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (a) $ — Natural gas: Beginning balance at January 1, 2015 $ (1 ) $ — $ (1 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: — 1 1 Settlements 1 (1 ) — Ending balance at December 31, 2015 $ — $ — $ — Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ — $ — Power: Beginning balance at January 1, 2015 $ 9 $ (142 ) $ (133 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: 2 (41 ) (39 ) Purchases 29 — 29 Settlements (23 ) 13 (10 ) Transfers out of Level 3 (1 ) — (1 ) Ending balance at December 31, 2015 $ 16 $ (170 ) $ (154 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (39 ) $ (39 ) Uranium: Beginning balance at January 1, 2015 $ (2 ) $ (a) $ (2 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 2 (a) 2 Ending balance at December 31, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (a) $ — (a) Not applicable. The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the year ended December 31, 2014 : Net Derivative Commodity Contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2014 $ 5 $ (a) $ 5 Realized and unrealized gains (losses) included in regulatory assets/liabilities: (9 ) (a) (9 ) Settlements (2 ) (a) (2 ) Ending balance at December 31, 2014 $ (6 ) $ (a) $ (6 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ (6 ) $ (a) $ (6 ) Natural gas: Beginning balance at January 1, 2014 $ — $ — $ — Realized and unrealized gains (losses) included in regulatory assets/liabilities: — 1 1 Purchases — (2 ) (2 ) Sales (1 ) — (1 ) Settlements — 1 1 Ending balance at December 31, 2014 $ (1 ) $ — $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ — $ 2 $ 2 Power: Beginning balance at January 1, 2014 $ 19 $ (108 ) $ (89 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (14 ) (39 ) (53 ) Purchases 34 — 34 Sales (1 ) — (1 ) Settlements (29 ) 5 (24 ) Ending balance at December 31, 2014 $ 9 $ (142 ) $ (133 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ — $ (43 ) $ (43 ) Uranium: Beginning balance at January 1, 2014 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 5 (a) 5 Ending balance at December 31, 2014 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ (1 ) $ (a) $ (1 ) (a) Not applicable. Transfers into or out of Level 3 represent either (1) existing assets and liabilities that were previously categorized as a higher level, but were recategorized to Level 3 because the inputs to the model became unobservable during the period, or (2) existing assets and liabilities that were previously classified as Level 3, but were recategorized to a higher level because the lowest significant input became observable during the period. Transfers between Level 1 and Level 3 for fuel oils and between Level 2 and Level 3 for power derivatives were primarily caused by changes in availability of similar financial trades observable on electronic exchanges between the periods. Any reclassifications are reported as transfers out of Level 3 at the fair value measurement reported at the beginning of the period in which the changes occur. See Note 11 – Retirement Benefits for the fair value hierarchy tables detailing Ameren’s pension and postretirement plan assets as of December 31, 2015 , as well as a table summarizing the changes in Level 3 plan assets during 2015 . The Ameren Companies’ carrying amounts of cash and cash equivalents approximate fair value because of the short-term nature of these instruments. They are considered to be Level 1 in the fair value hierarchy. The Ameren Companies' short-term borrowings also approximate fair value because of their short-term nature. Short-term borrowings are considered to be Level 2 in the fair value hierarchy as they are valued based on market rates for similar market transactions. The estimated fair value of long-term debt and preferred stock is based on the quoted market prices for same or similar issuances for companies with similar credit profiles or on the current rates offered to the Ameren Companies for similar financial instruments, which fair value measurement is considered Level 2 in the fair value hierarchy. The following table presents the carrying amounts and estimated fair values of our long-term debt, capital lease obligations and preferred stock at December 31, 2015 and 2014 : 2015 2014 Carrying Amount Fair Value Carrying Amount Fair Value Ameren: (a) Long-term debt and capital lease obligations (including current portion) (b) $ 7,275 $ 7,814 $ 6,205 $ 7,135 Preferred stock 142 125 142 122 Ameren Missouri: Long-term debt and capital lease obligations (including current portion) (b) $ 4,110 $ 4,449 $ 3,981 $ 4,518 Preferred stock 80 75 80 73 Ameren Illinois: Long-term debt (including current portion) (b) $ 2,471 $ 2,665 $ 2,224 $ 2,517 Preferred stock 62 50 62 49 (a) Preferred stock is recorded in "Noncontrolling Interests" on the consolidated balance sheet. (b) Carrying amounts reflect the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies |
Nuclear Decommissioning Trust F
Nuclear Decommissioning Trust Fund Investments | 12 Months Ended |
Dec. 31, 2015 | |
Investments, Debt and Equity Securities [Abstract] | |
NUCLEAR DECOMMISSIONING TRUST FUND INVESTMENTS | NUCLEAR DECOMMISSIONING TRUST FUND INVESTMENTS Ameren Missouri has investments in debt and equity securities that are held in a trust fund for the purpose of funding the decommissioning of its Callaway energy center. We have classified these investments as available for sale, and we have recorded all such investments at their fair market value at December 31, 2015 , and 2014 . See Note 10 – Callaway Energy Center for additional information. Investments in the nuclear decommissioning trust fund have a target allocation of 60 % to 70 % in equity securities, with the balance invested in debt securities. The following table presents proceeds from the sale and maturities of investments in Ameren Missouri’s nuclear decommissioning trust fund and the gross realized gains and losses resulting from those sales for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Proceeds from sales and maturities $ 349 $ 391 $ 196 Gross realized gains 8 7 7 Gross realized losses 2 2 5 Net realized and unrealized gains and losses are deferred and recorded as a regulatory asset or a regulatory liability on Ameren’s and Ameren Missouri’s balance sheets. This reporting is consistent with the method used to account for the decommissioning costs recovered in rates. Gains or losses associated with assets in the trust fund could result in lower or higher funding requirements for decommissioning costs, which are expected to be reflected in electric rates paid by Ameren Missouri’s customers. See Note 2 – Rate and Regulatory Matters. The following table presents the costs and fair values of investments in debt and equity securities in Ameren's and Ameren Missouri’s nuclear decommissioning trust fund at December 31, 2015 and 2014 : Security Type Cost Gross Unrealized Gain Gross Unrealized Loss Fair Value 2015 Debt securities $ 191 $ 2 $ 4 $ 189 Equity securities 147 224 7 364 Cash 4 — — 4 Other (a) (1 ) — — (1 ) Total $ 341 $ 226 $ 11 $ 556 2014 Debt securities $ 175 $ 7 $ — $ 182 Equity securities 138 230 4 364 Cash 1 — — 1 Other (a) 2 — — 2 Total $ 316 $ 237 $ 4 $ 549 (a) Represents payables relating to pending security purchases, net of receivables related to pending security sales and interest. The following table presents the costs and fair values of investments in debt securities in Ameren's and Ameren Missouri’s nuclear decommissioning trust fund according to their contractual maturities at December 31, 2015 : Cost Fair Value Less than 5 years $ 106 $ 105 5 years to 10 years 42 41 Due after 10 years 43 43 Total $ 191 $ 189 We have unrealized losses relating to certain available-for-sale investments included in our nuclear decommissioning trust fund, recorded as a regulatory asset as discussed above. Decommissioning will not occur until our nuclear energy center is retired. Ameren Missouri received a license extension from the NRC in March 2015 to extend the Callaway energy center’s operating license to 2044. The following table presents the fair value and the gross unrealized losses of the available-for-sale securities held in Ameren's and Ameren Missouri's nuclear decommissioning trust fund. They are aggregated by investment category and the length of time that individual securities have been in a continuous unrealized loss position at December 31, 2015 : Less than 12 Months 12 Months or Greater Total Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Debt securities $ 136 $ 3 $ 4 $ 1 $ 140 $ 4 Equity securities 16 3 4 4 20 7 Total $ 152 $ 6 $ 8 $ 5 $ 160 $ 11 |
Callaway Energy Center
Callaway Energy Center | 12 Months Ended |
Dec. 31, 2015 | |
Nuclear Waste Matters [Abstract] | |
CALLAWAY ENERGY CENTER | CALLAWAY ENERGY CENTER Under the NWPA, the DOE is responsible for disposing of spent nuclear fuel from the Callaway energy center and other commercial nuclear energy centers. Under the NWPA, Ameren Missouri and other owners of nuclear energy centers are responsible for paying the disposal costs. The NWPA established the fee that these utilities pay the federal government for disposing of the spent nuclear fuel at one mill, or one-tenth of one cent, for each kilowatthour generated and sold by those plants. The NWPA also requires the DOE to review the nuclear waste fee annually against the cost of the nuclear waste disposal program and to propose to the United States Congress any fee adjustment necessary to offset the costs of the program. As required by the NWPA, Ameren Missouri and other utilities have entered into standard contracts with the DOE. Consistent with the NWPA and its standard contract, Ameren Missouri had historically collected one mill from its electric customers for each kilowatthour of electricity that it generated and sold from its Callaway energy center. Because the federal government is not meeting its disposal obligation, the collection of this fee is currently suspended. Although both the NWPA and the standard contract stated that the DOE would begin to dispose of spent nuclear fuel by 1998, the DOE is not meeting its disposal obligation. The DOE's delay in carrying out its obligation to dispose of spent nuclear fuel from the Callaway energy center is not expected to adversely affect the continued operations of the energy center. Ameren Missouri has sufficient capacity in the spent fuel pool and dry spent storage facility at the Callaway energy center to store its spent nuclear fuel generated through the end of the energy center’s operating license in 2044. As a result of the DOE's failure to begin to dispose of spent nuclear fuel from commercial nuclear energy centers and fulfill its contractual obligations, Ameren Missouri and other nuclear energy center owners sued the DOE to recover costs, such as certain NRC fees and Missouri ad valorem taxes, incurred for ongoing storage of their spent fuel. The lawsuit resulted in a settlement agreement that provides for annual recovery of additional spent fuel storage and related costs incurred from 2010 through 2016, with the ability to extend the recovery period as mutually agreed upon by the parties. Included in these reimbursements are costs related to the dry spent fuel storage facility at the Callaway energy center, to which Ameren Missouri began transferring spent fuel assemblies in 2015. Ameren Missouri will continue to apply for reimbursement from the DOE for allowable costs associated with the ongoing storage of spent fuel. Electric utility rates charged to customers provide for the recovery of the Callaway energy center's decommissioning costs, which include decontamination, dismantling, and site restoration costs, over the expected life of the nuclear energy center. Amounts collected from customers are deposited into the external nuclear decommissioning trust fund to provide for the Callaway energy center’s decommissioning. It is assumed that the Callaway energy center site will be decommissioned through the immediate dismantlement method and removed from service. Ameren and Ameren Missouri have recorded an ARO for the Callaway energy center decommissioning costs at fair value, which represents the present value of estimated future cash outflows. Annual decommissioning costs of $7 million are included in the costs used to establish electric rates for Ameren Missouri's customers. Every three years, the MoPSC requires Ameren Missouri to file an updated cost study and funding analysis for decommissioning its Callaway energy center. Following the NRC’s decision in March 2015 to extend the Callaway energy center’s operating license from 2024 to 2044, an updated cost study and a revised funding analysis were filed with the MoPSC in April 2015. Ameren Missouri’s April 2015 filing supported no change in electric service rates for decommissioning costs. There is no time requirement by which the MoPSC must issue an order regarding the decommissioning cost included in Ameren Missouri’s electric service rates. If the assumed return on trust assets is not earned, we believe that it is probable that any such earnings deficiency will be recovered in rates. The fair value of the trust fund for Ameren Missouri's Callaway energy center is reported as "Nuclear decommissioning trust fund" in Ameren's and Ameren Missouri's balance sheets. This amount is legally restricted and may be used only to fund the costs of nuclear decommissioning. Changes in the fair value of the trust fund are recorded as an increase or decrease to the nuclear decommissioning trust fund, with an offsetting adjustment to the related regulatory liability. See Note 2 – Rate and Regulatory Matters and Note 9 – Nuclear Decommissioning Trust Fund Investments for additional information related to the Callaway energy center. |
Retirement Benefits
Retirement Benefits | 12 Months Ended |
Dec. 31, 2015 | |
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract] | |
RETIREMENT BENEFITS | RETIREMENT BENEFITS The primary objective of the Ameren pension and postretirement benefit plans is to provide eligible employees with pension and postretirement health care and life insurance benefits. Ameren offers defined benefit pension and postretirement benefit plans covering substantially all of its union employees. Ameren offers defined benefit pension plans covering substantially all of its non-union employees and postretirement benefit plans covering non-union employees hired before October 2015. Ameren uses a measurement date of December 31 for its pension and postretirement benefit plans. Ameren Missouri and Ameren Illinois each participate in Ameren’s single-employer pension and other postretirement plans. Ameren’s qualified pension plan is the Ameren Retirement Plan. Ameren also has an unfunded nonqualified pension plan, the Ameren Supplemental Retirement Plan, which is available to provide certain management employees and retirees with a supplemental benefit when their qualified pension plan benefits are capped in compliance with Internal Revenue Code limitations. Ameren’s other postretirement plans are the Ameren Retiree Medical Plan and the Ameren Group Life Insurance Plan. Only Ameren subsidiaries participate in the plans listed above. In December 2013, Ameren completed the divestiture of New AER to IPH. In accordance with the transaction agreement, Ameren retained the pension obligations as of December 2, 2013, associated with the current and former employees of New AER and its subsidiaries who were included in the Ameren Retirement Plan and the Ameren Supplemental Retirement Plan. Ameren also retained the postretirement benefit obligations associated with the employees of New AER and its subsidiaries who were eligible to retire at December 2, 2013, and who were included in the Ameren Retiree Medical Plan and the Ameren Group Life Insurance Plan. Ameren’s unfunded obligation under its pension and other postretirement benefit plans was $567 million and $710 million as of December 31, 2015 , and December 31, 2014 , respectively. These net liabilities are recorded in "Other current liabilities," "Pension and other postretirement benefits," and "Other assets" on Ameren's consolidated balance sheet. The primary factor contributing to the decrease in the unfunded obligation during 2015 was a 50 basis point increase in the pension and other postretirement benefit plan discount rates used to determine the present value of the obligation. The decrease in the unfunded obligation also resulted in a decrease to "Regulatory assets" on Ameren's, Ameren Missouri's, and Ameren Illinois' consolidated balance sheet. The following table presents the net benefit liability recorded on the balance sheets of each of the Ameren Companies as of December 31, 2015 and 2014 : 2015 2014 Ameren (a) $ 567 $ 710 Ameren Missouri 236 277 Ameren Illinois 219 278 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. Ameren recognizes the underfunded status of its pension and postretirement plans as a liability on its consolidated balance sheet, with offsetting entries to accumulated OCI and regulatory assets, in accordance with authoritative accounting guidance. The following table presents the funded status of Ameren's pension and postretirement benefit plans as of December 31, 2015 and 2014 . It also provides the amounts included in regulatory assets and accumulated OCI at December 31, 2015 and 2014 , that have not been recognized in net periodic benefit costs. 2015 2014 Pension Benefits (a) Postretirement Benefits (a) Pension Benefits (a) Postretirement Benefits (a) Accumulated benefit obligation at end of year $ 3,995 $ (b) $ 4,176 $ (b) Change in benefit obligation: Net benefit obligation at beginning of year $ 4,410 $ 1,203 $ 3,900 $ 1,096 Service cost 92 24 79 19 Interest cost 174 48 183 50 Participant contributions — 8 — 16 Actuarial (gain) loss (256 ) (133 ) 462 84 Settlement (2 ) — — — Benefits paid (221 ) (56 ) (214 ) (65 ) Federal subsidy on benefits paid (b) — (b) 3 Net benefit obligation at end of year 4,197 1,094 4,410 1,203 Change in plan assets: Fair value of plan assets at beginning of year 3,794 1,109 3,461 1,074 Actual return on plan assets (29 ) (8 ) 448 75 Employer contributions 111 18 99 6 Federal subsidy on benefits paid (b) — (b) 3 Participant contributions — 8 — 16 Settlements (2 ) — — — Benefits paid (221 ) (56 ) (214 ) (65 ) Fair value of plan assets at end of year 3,653 1,071 3,794 1,109 Funded status – deficiency 544 23 616 94 Accrued benefit cost at December 31 $ 544 $ 23 $ 616 $ 94 Amounts recognized in the balance sheet consist of: Noncurrent asset (c) $ — $ (18 ) $ — $ — Current liability (d) 3 2 3 2 Noncurrent liability 541 39 613 92 Net liability recognized $ 544 $ 23 $ 616 $ 94 Amounts recognized in regulatory assets consist of: Net actuarial (gain) loss $ 395 $ (82 ) $ 452 $ (7 ) Prior service cost (credit) (5 ) (11 ) (6 ) (16 ) Amounts (pretax) recognized in accumulated OCI consist of: Net actuarial (gain) loss 17 (3 ) 29 (5 ) Prior service cost (credit) — — — (1 ) Total $ 407 $ (96 ) $ 475 $ (29 ) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) Not applicable. (c) Included in "Other assets" on Ameren's consolidated balance sheet. (d) Included in "Other current liabilities" on Ameren's consolidated balance sheet. The following table presents the assumptions used to determine our benefit obligations at December 31, 2015 and 2014 : Pension Benefits Postretirement Benefits 2015 2014 2015 2014 Discount rate at measurement date 4.50 % 4.00 % 4.50 % 4.00 % Increase in future compensation 3.50 3.50 3.50 3.50 Medical cost trend rate (initial) (a) (a) 5.00 5.00 Medical cost trend rate (ultimate) (a) (a) 5.00 5.00 Years to ultimate rate (a) (a) — — (a) Not applicable Ameren determines discount rate assumptions by identifying a theoretical settlement portfolio of high-quality corporate bonds sufficient to provide for a plan's projected benefit payments. The settlement portfolio of bonds is selected from a pool of more than 700 high-quality corporate bonds. A single discount rate is then determined; that rate results in a discounted value of the plan's benefit payments that equates to the market value of the selected bonds. In addition, during 2015, Ameren adopted the Society of Actuaries 2015 Mortality Tables Report and Mortality Improvement Scale. The updated mortality tables assume a lower rate of mortality improvement as compared to the 2014 Mortality Tables Report and Mortality Improvement Scale that Ameren adopted in 2014. The 2015 tables lowered projected improvements in life expectancies for our employees and retirees, resulting in a decrease to our pension and other postretirement benefit obligations. Funding Pension benefits are based on the employees’ years of service, age, and compensation. Ameren’s pension plans are funded in compliance with income tax regulations, federal funding, and other regulatory requirements. As a result, Ameren expects to fund its pension plan at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering its assumptions at December 31, 2015 , its investment performance in 2015, and its pension funding policy, Ameren expects to make annual contributions of $40 million to $70 million in each of the next five years, with aggregate estimated contributions of $280 million . We expect Ameren Missouri’s and Ameren Illinois’ portion of the future funding requirements to be 40% and 50% , respectively. These amounts are estimates. They may change based on actual investment performance, changes in interest rates, changes in our assumptions, changes in government regulations, and any voluntary contributions. Our funding policy for postretirement benefits is primarily to fund the Voluntary Employee Beneficiary Association (VEBA) trusts to match the annual postretirement expense. The following table presents the cash contributions made to our defined benefit retirement plan and to our postretirement plans during 2015 , 2014 , and 2013 : Pension Benefits Postretirement Benefits 2015 2014 2013 2015 2014 2013 Ameren Missouri $ 47 $ 41 $ 60 $ 8 $ 3 $ 10 Ameren Illinois 45 39 50 8 2 11 Other 19 19 46 2 1 4 Ameren (a) 111 99 156 18 6 25 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. Investment Strategy and Policies Ameren manages plan assets in accordance with the “prudent investor” guidelines contained in ERISA. The investment committee, which includes members of senior management, approves and implements investment strategy and asset allocation guidelines for the plan assets. The investment committee’s goals are twofold: first, to ensure that sufficient funds are available to provide the benefits at the time they are payable; and second, to maximize total return on plan assets and to minimize expense volatility consistent with its tolerance for risk. Ameren delegates the task of investment management to specialists in each asset class. As appropriate, Ameren provides each investment manager with guidelines that specify allowable and prohibited investment types. The investment committee regularly monitors manager performance and compliance with investment guidelines. The expected return on plan assets assumption is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Projected rates of return for each asset class were estimated after an analysis of historical experience, future expectations, and the volatility of the various asset classes. After considering the target asset allocation for each asset class, we adjusted the overall expected rate of return for the portfolio for historical and expected experience of active portfolio management results compared with benchmark returns and for the effect of expenses paid from plan assets. Ameren will use an expected return on plan assets for its pension and postretirement plan assets of 7.00% , in 2016. No plan assets are expected to be returned to Ameren during 2016. Ameren’s investment committee strives to assemble a portfolio of diversified assets that does not create a significant concentration of risks. The investment committee develops asset allocation guidelines between asset classes, and it creates diversification through investments in assets that differ by type (equity, debt, real estate, private equity), duration, market capitalization, country, style (growth or value) and industry, among other factors. The diversification of assets is displayed in the target allocation table below. The investment committee also routinely rebalances the plan assets to adhere to the diversification goals. The investment committee’s strategy reduces the concentration of investment risk; however, Ameren is still subject to overall market risk. The following table presents our target allocations for 2016 and our pension and postretirement plans’ asset categories as of December 31, 2015 and 2014 : Asset Category Target Allocation 2016 Percentage of Plan Assets at December 31, 2015 2014 Pension Plan: Cash and cash equivalents 0% – 5% 1 % 2 % Equity securities: U.S. large-capitalization 29% – 39% 34 % 34 % U.S. small- and mid-capitalization 3% – 13% 7 % 7 % International and emerging markets 9% – 19% 13 % 12 % Total equity 51% – 61% 54 % 53 % Debt securities 35% – 45% 40 % 41 % Real estate 0% – 9% 5 % 4 % Private equity 0% – 5% (a) (a) Total 100 % 100 % Postretirement Plans: Cash and cash equivalents 0% – 7% 4 % 4 % Equity securities: U.S. large-capitalization 34% – 44% 39 % 40 % U.S. small- and mid-capitalization 2% – 12% 7 % 7 % International 9% – 19% 13 % 13 % Total equity 55% – 65% 59 % 60 % Debt securities 33% – 43% 37 % 36 % Total 100 % 100 % (a) Less than 1% of plan assets. In general, the United States large-capitalization equity investments are passively managed or indexed, whereas the international, emerging markets, United States small-capitalization, and United States mid-capitalization equity investments are actively managed by investment managers. Debt securities include a broad range of fixed-income vehicles. Debt security investments in high-yield securities, emerging market securities, and non-United-States-dollar-denominated securities are owned by the plans, but in limited quantities to reduce risk. Most of the debt security investments are under active management by investment managers. Real estate investments include private real estate vehicles; however, Ameren does not, by policy, hold direct investments in real estate property. Ameren’s investment in private equity funds is spread among eight different limited partnerships, with invested capital ranging from less than $1 million to $4 million in each, which invest primarily in a diversified number of small United States-based companies. Ameren is seeking to eliminate its private equity investments over time. Additionally, Ameren’s investment committee allows investment managers to use derivatives, such as index futures, exchange traded funds, foreign exchange futures, and options, in certain situations, to increase or to reduce market exposure in an efficient and timely manner. Fair Value Measurements of Plan Assets Investments in the pension and postretirement benefit plans were stated at fair value as of December 31, 2015 . The fair value of an asset is the amount that would be received upon its sale in an orderly transaction between market participants at the measurement date. Cash and cash equivalents have initial maturities of three months or less and are recorded at cost plus accrued interest. The carrying amounts of cash and cash equivalents approximate fair value because of the short-term nature of these instruments. Investments traded in active markets on national or international securities exchanges are valued at closing prices on the last business day on or before the measurement date. Securities traded in over-the-counter markets are valued based on quoted market prices, broker or dealer quotations, or alternative pricing sources with reasonable levels of price transparency. Investments measured under net asset valuation are based on the fair values of the underlying assets provided by the funds and their administrators. Derivative contracts are valued at fair value, as determined by the investment managers (or independent third parties on behalf of the investment managers), who use proprietary models and take into consideration exchange quotations on underlying instruments, dealer quotations, and other market information. The fair value of real estate is based on annual appraisal reports prepared by an independent real estate appraiser. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2015 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ — $ 20 $ — $ 20 Equity securities: U.S. large-capitalization — 1,296 — 1,296 U.S. small- and mid-capitalization 268 — — 268 International and emerging markets 122 369 — 491 Debt securities: Corporate bonds — 631 — 631 Municipal bonds — 104 — 104 U.S. Treasury and agency securities 6 751 — 757 Other — 5 — 5 Real estate — — 168 168 Private equity — — 8 8 Total $ 396 $ 3,176 $ 176 $ 3,748 Less: Medical benefit assets at December 31 (a) (123 ) Plus: Net receivables at December 31 (b) 28 Fair value of pension plans assets at year end $ 3,653 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2014 : Quoted Prices in Active Markets for Identified Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ — $ 38 $ — $ 38 Equity securities: U.S. large-capitalization — 1,331 — 1,331 U.S. small- and mid-capitalization 270 — — 270 International and emerging markets 134 360 — 494 Debt securities: Corporate bonds — 1,026 — 1,026 Municipal bonds — 175 — 175 U.S. Treasury and agency securities 6 366 — 372 Other — 31 — 31 Real estate — — 147 147 Private equity — — 13 13 Derivative assets 1 — — 1 Total $ 411 $ 3,327 $ 160 $ 3,898 Less: Medical benefit assets at December 31 (a) (125 ) Plus: Net receivables at December 31 (b) 21 Fair value of pension plans assets at year end $ 3,794 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. The following table summarizes the changes in the fair value of the pension plan assets classified as Level 3 in the fair value hierarchy for each of the years ended December 31, 2015 and 2014 : Beginning Balance at January 1, Actual Return on Plan Assets Related to Assets Still Held at the Reporting Date Actual Return on Plan Assets Related to Assets Sold During the Period Purchases, Sales, and Settlements, Net Net Transfers into (out of) of Level 3 Ending Balance at December 31, 2015: Real estate $ 147 $ 14 $ — $ 7 $ — $ 168 Private equity 13 (9 ) 9 (5 ) — 8 2014: Real estate $ 131 $ 11 $ — $ 5 $ — $ 147 Private equity 15 (9 ) 10 (3 ) — 13 The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the postretirement benefit plans assets measured at fair value as of December 31, 2015 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ 61 $ — $ — $ 61 Equity securities: U.S. large-capitalization 272 98 — 370 U.S. small- and mid-capitalization 65 — — 65 International 33 93 — 126 Other — 7 — 7 Debt securities: Corporate bonds — 138 — 138 Municipal bonds — 114 — 114 U.S. Treasury and agency securities — 55 — 55 Other — 40 — 40 Total $ 431 $ 545 $ — $ 976 Plus: Medical benefit assets at December 31 (a) 123 Less: Net payables at December 31 (b) (28 ) Fair value of postretirement benefit plans assets at year end $ 1,071 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by interest receivables and receivables related to pending security sales. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the postretirement benefit plans assets measured at fair value as of December 31, 2014 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ 89 $ — $ — $ 89 Equity securities: U.S. large-capitalization 291 101 — 392 U.S. small- and mid-capitalization 70 — — 70 International 37 94 — 131 Other — 7 — 7 Debt securities: Corporate bonds — 105 — 105 Municipal bonds — 111 — 111 U.S. Treasury and agency securities — 89 — 89 Other — 44 — 44 Total $ 487 $ 551 $ — $ 1,038 Plus: Medical benefit assets at December 31 (a) 125 Less: Net payables at December 31 (b) (54 ) Fair value of postretirement benefit plans assets at year end $ 1,109 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by Medicare, interest receivables, and receivables related to pending security sales. Net Periodic Benefit Cost The following table presents the components of the net periodic benefit cost of Ameren's pension and postretirement benefit plans during 2015 , 2014 , and 2013 : Pension Benefits (a) Postretirement Benefits (a) 2015 Service cost $ 92 $ 24 Interest cost 174 48 Expected return on plan assets (248 ) (68 ) Amortization of: Prior service credit (1 ) (5 ) Actuarial loss 74 5 Settlement Loss 1 — Net periodic benefit cost $ 92 $ 4 2014 Service cost $ 79 $ 19 Interest cost 183 50 Expected return on plan assets (229 ) (65 ) Amortization of: Prior service credit (1 ) (5 ) Actuarial (gain) loss 49 (7 ) Net periodic benefit cost (benefit) $ 81 $ (8 ) 2013 Service cost $ 91 $ 22 Interest cost 163 46 Expected return on plan assets (218 ) (62 ) Amortization of: Prior service credit (2 ) (6 ) Actuarial loss 87 8 Curtailment gain (12 ) (7 ) Net periodic benefit cost (b) $ 109 $ 1 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) The net periodic benefit cost includes a $6 million and a $7 million net gain for pension benefits and postretirement benefits, respectively, which was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). This net gain includes the curtailment gain recognized in 2013 as a result of a significant reduction in employees as of the December 2, 2013 closing date of the New AER divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. The estimated amounts that will be amortized from regulatory assets and accumulated OCI into Ameren's net periodic benefit cost in 2016 are as follows: Pension Benefits (a) Postretirement Benefits (a) Regulatory assets: Prior service credit $ (1 ) $ (4 ) Net actuarial loss 46 (3 ) Accumulated OCI: Net actuarial (gain) loss (3 ) (2 ) Total $ 42 $ (9 ) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. Prior service cost is amortized on a straight-line basis over the average future service of active participants benefiting under the plan amendment. The net actuarial (gain) loss subject to amortization is amortized on a straight-line basis over 10 years. The Ameren Companies are responsible for their share of the pension and postretirement benefit costs. The following table presents the pension costs and the postretirement benefit costs incurred and included in continuing operations for the years ended December 31, 2015 , 2014 , and 2013 : Pension Costs Postretirement Costs 2015 2014 2013 2015 2014 2013 Ameren Missouri (a) $ 54 $ 50 $ 69 $ 8 $ 3 $ 8 Ameren Illinois 38 30 41 (3 ) (9 ) — Other — 1 5 (1 ) (2 ) — Ameren (b) 92 81 115 4 (8 ) 8 (a) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. (b) Includes amounts for Ameren registrant and nonregistrant subsidiaries. The expected pension and postretirement benefit payments from qualified trust and company funds, which reflect expected future service, as of December 31, 2015 , are as follows: Pension Benefits Postretirement Benefits Paid from Qualified Trust Funds Paid from Company Funds Paid from Qualified Trust Funds Paid from Company Funds 2016 $ 233 $ 3 $ 55 $ 2 2017 244 3 58 2 2018 250 3 60 2 2019 257 3 62 2 2020 261 3 65 2 2021 – 2025 1,377 13 341 12 The following table presents the assumptions used to determine net periodic benefit cost for our pension and postretirement benefit plans for the years ended December 31, 2015 , 2014 , and 2013 : Pension Benefits Postretirement Benefits 2015 2014 2013 2015 2014 2013 Discount rate at measurement date 4.00 % 4.75 % 4.00 % 4.00 % 4.75 % 4.00 % Expected return on plan assets 7.25 7.25 7.50 7.00 7.00 7.25 Increase in future compensation 3.50 3.50 3.50 3.50 3.50 3.50 Medical cost trend rate (initial) (a) (a) (a) 5.00 5.00 5.00 Medical cost trend rate (ultimate) (a) (a) (a) 5.00 5.00 5.00 Years to ultimate rate (a) (a) (a) — — — (a) Not applicable The table below reflects the sensitivity of Ameren’s plans to potential changes in key assumptions: Pension Benefits Postretirement Benefits Service Cost and Interest Cost Projected Benefit Obligation Service Cost and Interest Cost Postretirement Benefit Obligation 0.25% decrease in discount rate $ (1 ) $ 130 $ 1 $ 37 0.25% increase in salary scale 2 14 — — 1.00% increase in annual medical trend — — 3 44 1.00% decrease in annual medical trend — — (3 ) (44 ) Other Ameren sponsors a 401(k) plan for eligible employees. The Ameren 401(k) plan covered all eligible employees at December 31, 2015 . The plan allows employees to contribute a portion of their compensation in accordance with specific guidelines. Ameren matches a percentage of the employee contributions up to certain limits. The following table presents the portion of the matching contribution to the Ameren 401(k) plan attributable to the continuing operations for each of the Ameren Companies for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri $ 16 $ 16 $ 16 Ameren Illinois 12 11 10 Other 1 1 1 Ameren (a) 29 28 27 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Stock-Based Compensation
Stock-Based Compensation | 12 Months Ended |
Dec. 31, 2015 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
STOCK-BASED COMPENSATION | STOCK-BASED COMPENSATION The 2014 Incentive Plan is Ameren’s long-term stock compensation plan for eligible employees and directors. The 2006 Incentive Plan was replaced prospectively for new grants beginning in April 2014. The 2014 Incentive Plan provides for a maximum of 8 million common shares to be available for grant to eligible employees and directors. To the extent that the issuance of a share that is subject to an outstanding award under the 2006 Incentive Plan would cause Ameren to exceed the maximum authorized shares under the 2006 Incentive Plan, the issuance of that share will take place under the 2014 Incentive Plan. This will reduce the maximum number of shares that may be granted under the 2014 Incentive Plan. The 2014 Incentive Plan awards may be stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance share units, cash-based awards, and other stock-based awards. A summary of nonvested shares at December 31, 2015 , and changes during the year ended December 31, 2015 , under the 2006 Incentive Plan and the 2014 Incentive Plan are presented below: Performance Share Units Share Units Weighted-average Fair Value per Share Unit Nonvested at January 1, 2015 1,162,377 $ 35.35 Granted (a) 570,313 52.88 Forfeitures (1,944 ) 34.75 Earned and vested (b) (705,876 ) 33.93 Nonvested at December 31, 2015 1,024,870 $ 46.08 (a) Includes performance share units (share units) granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. (b) Includes share units granted in 2013 that vested as of December 31, 2015 , that were earned pursuant to the terms of the award grants. Also includes share units that vested due to attainment of retirement eligibility by certain employees. Actual shares issued for retirement-eligible employees will vary depending on actual performance over the three-year measurement period. Ameren recorded compensation expense of $19 million , $19 million , and $20 million for the years ended December 31, 2015 , 2014 , and 2013 , respectively, and a related tax benefit of $7 million , $7 million , and $8 million for the years ended December 31, 2015 , 2014 , and 2013 , respectively. Ameren settled performance share units of $27 million , $33 million , and $11 million for the years ended December 31, 2015 , 2014 , and 2013 . There were no significant compensation costs capitalized related to the performance share units during the years ended December 31, 2015 , 2014 , and 2013 . As of December 31, 2015 , total compensation cost of $21 million related to nonvested awards not yet recognized is expected to be recognized over a weighted-average period of 23 months . Performance Share Units A share unit vests and entitles an employee to receive shares of Ameren common stock (plus accumulated dividends) if, at the end of the three -year performance period, certain specified performance or market conditions have been met and if the individual remains employed by Ameren through the required vesting period. The exact number of shares issued pursuant to a share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the performance goals. The vesting period for share units awarded in 2015 extended beyond the three-year performance period to the payout date, while the vesting period for share units awarded in 2013 and 2014 matched the three-year performance period. The fair value of each share unit awarded in 2015 under the 2014 Incentive Plan was determined to be $52.88 , which was based on Ameren's closing common share price of $46.13 at December 31, 2014 , and lattice simulations. Lattice simulations are used to estimate expected share payout based on Ameren's total shareholder return for a three -year performance period relative to the designated peer group beginning January 1, 2015 . The simulations can produce a greater fair value for the share unit than the applicable closing common share price because they include the weighted payout scenarios in which an increase in the share price has occurred. The significant assumptions used to calculate fair value also included a three-year risk-free rate of 1.10% , volatility of 12% to 18% for the peer group, and Ameren's attainment of a three-year average earnings per share threshold during the performance period. The fair value of each share unit awarded in 2014 , excluding the grants issued in April 2014 for certain executive officers, under the 2006 Incentive Plan and the 2014 Incentive Plan was determined to be $38.90 , which was based on Ameren’s closing common share price of $36.16 at December 31, 2013 , and lattice simulations. Lattice simulations are used to estimate expected share payout based on Ameren’s total shareholder return for a three -year performance period relative to the designated peer group beginning January 1, 2014 . The significant assumptions used to calculate fair value also included a three-year risk-free rate of 0.78% , volatility of 12% to 18% for the peer group, and Ameren’s attainment of a three-year average earnings per share threshold during the performance period. |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2015 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | INCOME TAXES The following table presents the principal reasons for the difference between the effective income tax rate and the statutory federal income tax rate for the years ended December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Ameren 2015 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Depreciation differences — (2 ) (1 ) Amortization of investment tax credit (1 ) — (1 ) State tax 3 5 5 Other permanent items — (1 ) — Effective income tax rate 37 % 37 % 38 % 2014 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Amortization of investment tax credit (1 ) — (1 ) State tax 3 6 4 Other permanent items — — 1 Effective income tax rate 37 % 41 % 39 % 2013 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Depreciation differences — (1 ) — Amortization of investment tax credit (1 ) — (1 ) State tax 3 6 4 Other permanent items 1 — — Effective income tax rate 38 % 40 % 38 % The following table presents the components of income tax expense (benefit) for the years ended December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Other Ameren 2015 Current taxes: Federal $ 110 $ (83 ) $ (29 ) $ (2 ) State 17 (11 ) (10 ) (4 ) Deferred taxes: Federal 71 193 35 299 State 16 29 31 76 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense $ 209 $ 127 $ 27 $ 363 2014 Current taxes: Federal $ (13 ) $ (51 ) $ 27 $ (37 ) State (3 ) (2 ) (32 ) (37 ) Deferred taxes: Federal 222 159 (12 ) 369 State 28 38 22 88 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense $ 229 $ 143 $ 5 $ 377 2013 Current taxes: Federal $ 136 $ (15 ) $ (239 ) (a) $ (118 ) State 41 21 (43 ) (a) 19 Deferred taxes: Federal 64 99 205 (a) 368 State 6 6 36 (a) 48 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense (benefit) $ 242 $ 110 $ (41 ) $ 311 (a) These amounts are substantially related to the reversal of unrecognized tax benefits as a result of IRS guidance related to the deductibility of expenditures to maintain, replace, or improve steam or electric power generation property, along with casualty loss deductions for storm damage. The amounts also reflect the increase in deferred tax expense due to available net operating losses. The Illinois corporate income tax rate was increased to 9.5% from January 2011 through December 2014. The tax rate decreased to 7.75% on January 1, 2015, and is scheduled to decrease to 7.3% on January 1, 2025. The following table presents the deferred tax assets and deferred tax liabilities recorded as a result of temporary differences at December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Other Ameren 2015 Accumulated deferred income taxes, net liability (asset): Plant related $ 2,931 $ 1,587 $ 37 $ 4,555 Regulatory assets, net 81 (1 ) — 80 Deferred employee benefit costs (76 ) (40 ) (91 ) (207 ) Revenue requirement reconciliation adjustments — 66 — 66 Tax carryforwards (65 ) (133 ) (405 ) (603 ) Other (27 ) 1 20 (6 ) Total net accumulated deferred income tax liabilities (assets) (a) $ 2,844 $ 1,480 $ (439 ) $ 3,885 2014 Accumulated deferred income taxes, net liability (asset): Plant related $ 2,776 $ 1,393 $ 16 $ 4,185 Regulatory assets, net 82 (5 ) 1 78 Deferred employee benefit costs (80 ) (45 ) (95 ) (220 ) Revenue requirement reconciliation adjustments — 66 3 69 Tax carryforwards (107 ) (139 ) (429 ) (675 ) Other 86 (22 ) 70 134 Total net accumulated deferred income tax liabilities (assets) (a) $ 2,757 $ 1,248 $ (434 ) $ 3,571 (a) Reflects the adoption of the new authoritative accounting guidance for the balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. The following table presents the components of deferred tax assets relating to net operating loss carryforwards, tax credit carryforwards, and charitable contribution carryforwards at December 31, 2015 : Ameren Missouri Ameren Illinois Other Ameren Net operating loss carryforwards: Federal (a) $ 35 $ 127 $ 245 $ 407 State (b) 4 4 38 46 Total net operating loss carryforwards $ 39 $ 131 $ 283 $ 453 Tax credit carryforwards: Federal (c) $ 26 $ 1 $ 78 $ 105 State (d) — 1 40 41 State valuation allowance (e) — — (2 ) (2 ) Total tax credit carryforwards $ 26 $ 2 $ 116 $ 144 Charitable contribution carryforwards (f) $ — $ — $ 10 $ 10 Valuation allowance (e) — — (4 ) (4 ) Total charitable contribution carryforwards $ — $ — $ 6 $ 6 (a) Will begin to expire in 2029 . (b) Will begin to expire in 2023 . (c) Will begin to expire in 2029 . (d) Will begin to expire in 2016 . (e) See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. (f) Will begin to expire in 2016 . The following table presents the components of deferred tax assets relating to net operating loss carryforwards, tax credit carryforwards, and charitable contribution carryforwards at December 31, 2014 : Ameren Missouri Ameren Illinois Other Ameren Net operating loss carryforwards: Federal (a) $ 75 $ 127 $ 255 $ 457 State (b) 11 10 53 74 Total net operating loss carryforwards $ 86 $ 137 $ 308 $ 531 Tax credit carryforwards: Federal (c) $ 21 $ 1 $ 77 $ 99 State (d) 1 2 33 36 State valuation allowance (e) (1 ) (1 ) (2 ) (4 ) Total tax credit carryforwards $ 21 $ 2 $ 108 $ 131 Charitable contribution carryforwards (f) $ — $ — $ 19 $ 19 Valuation allowance (e) — — (6 ) (6 ) Total charitable contribution carryforwards $ — $ — $ 13 $ 13 (a) Will begin to expire in 2028 (b) Will begin to expire in 2019 . (c) Will begin to expire in 2029 . (d) Began to expire in 2013 . (e) See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. (f) Began to expire in 2013 . Uncertain Tax Positions A reconciliation of the change in the unrecognized tax benefit balance during the years ended December 31, 2013 , 2014 , and 2015 , is as follows: Ameren Missouri Ameren Illinois Other Ameren Unrecognized tax benefits – January 1, 2013 $ 136 $ 13 $ 7 $ 156 Increases based on tax positions prior to 2013 — 2 5 7 Decreases based on tax positions prior to 2013 (122 ) (16 ) (5 ) (143 ) Increases based on tax positions related to 2013 16 — 53 (a) 69 Changes related to settlements with taxing authorities — — — — Decreases related to the lapse of statute of limitations 1 — — 1 Unrecognized tax benefits – December 31, 2013 $ 31 $ (1 ) $ 60 $ 90 Increases based on tax positions prior to 2014 1 1 4 6 Decreases based on tax positions prior to 2014 (32 ) (1 ) (9 ) (42 ) Increases based on tax positions related to 2014 — — — — Changes related to settlements with taxing authorities — — — — Increases related to the lapse of statute of limitations — — — — Unrecognized tax benefits – December 31, 2014 $ — $ (1 ) $ 55 $ 54 Increases based on tax positions prior to 2015 — 1 1 2 Decreases based on tax positions prior to 2015 — — (56 ) (a) (56 ) Increases based on tax positions related to 2015 — — — — Changes related to settlements with taxing authorities — — — — Increases related to the lapse of statute of limitations — — — — Unrecognized tax benefits – December 31, 2015 $ — $ — $ — $ — Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2013 $ 3 $ — $ 51 (a) $ 54 Total unrecognized tax benefits (detriments) that, if recognized, would affect the effective tax rates as of December 31, 2014 $ — $ (1 ) $ 53 (a) $ 52 Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2015 $ — $ — $ — $ — (a) Primarily due to tax positions relating to the New AER divestiture. The income statement impact of this unrecognized tax benefit was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. The Ameren Companies recognize interest charges (income) and penalties accrued on tax liabilities on a pretax basis as interest charges (income) or miscellaneous expense, respectively, in the statements of income. A reconciliation of the change in the liability for interest on unrecognized tax benefits during the years ended December 31, 2013 , 2014 , and 2015 , is as follows: Ameren Missouri Ameren Illinois Other Ameren Liability for interest – January 1, 2013 $ 8 $ 1 $ (3 ) $ 6 Interest charges (income) for 2013 (8 ) (1 ) 4 (5 ) Liability for interest – December 31, 2013 $ — $ — $ 1 $ 1 Interest charges (income) for 2014 — — (1 ) (1 ) Liability for interest – December 31, 2014 $ — $ — $ — $ — Interest charges (income) for 2015 — — — — Liability for interest – December 31, 2015 $ — $ — $ — $ — As of December 31, 2013 , 2014 , and 2015 , the Ameren Companies have accrued no amount for penalties with respect to unrecognized tax benefits. In 2015, final settlements for tax years 2012 and 2013 were reached with the IRS. There were no uncertain tax positions related to the 2012 tax year, as of December 31, 2014, so this settlement did not affect the amount of recorded unrecognized tax benefits during 2015. The settlement related to the 2013 tax year resolved the uncertain tax position associated with the final tax basis of New AER and the related tax benefit resulting from the divested merchant generation business. The settlement resulted in a reduction of Ameren's unrecognized tax benefits of $53 million and an increase to net income from discontinued operations. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. In 2014, final settlements for tax years 2007 through 2011 were reached with the IRS. These settlements, which resolved the uncertain tax positions associated with the timing of research tax deductions for these years, resulted in a decrease in Ameren’s and Ameren Missouri’s unrecognized tax benefits of $20 million , and $13 million , respectively. In addition, the settlement for tax years 2007 through 2011 provided certainty for the previously uncertain tax positions associated with the timing of research tax deductions for the remaining open tax years of 2012, 2013, and 2014. The certainty provided from the settlement resulted in an $18 million decrease in both Ameren’s and Ameren Missouri’s unrecognized tax benefits. The settlement also resulted in a $2 million increase to Ameren’s state unrecognized tax benefits. The net reduction in unrecognized tax benefits in 2014 did not materially affect income tax expense for the Ameren Companies. In 2013, unrecognized tax benefits related to the deductibility of expenditures to maintain, replace, or improve steam or electric power generation property, along with casualty loss deductions for storm damage, were reduced by $103 million , $95 million , and $5 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively. This reduction in unrecognized tax benefits did not affect income tax expense for the Ameren Companies. However, the liability for interest related to these unrecognized tax benefits was released in 2013. In 2013, Ameren adopted an accounting method change as a result of guidance issued by the IRS, with respect to the amount and timing of the deductions to maintain, replace, or improve generation property. State income tax returns are generally subject to examination for a period of three years after filing. The state impact of any federal changes remains subject to examination by various states for up to one year after formal notification to the states. The Ameren Companies currently do not have material state income tax issues under examination, administrative appeals, or litigation. Ameren Missouri has an uncertain tax position tracker. Under Missouri's regulatory framework, uncertain tax positions do not reduce Ameren Missouri's electric rate base. When an uncertain income tax position liability is resolved, the MoPSC requires, through the uncertain tax position tracker, the creation of a regulatory asset or regulatory liability to reflect the time value, using the weighted-average cost of capital included in each of the electric rate orders in effect before the tax position was resolved, of the difference between the uncertain tax position liability that was excluded from rate base and the final tax liability. The resulting regulatory asset or liability will affect earnings in the year it is created and then will be amortized over three years, beginning on the effective date of new rates established in the next electric rate case. |
Related Party Transactions
Related Party Transactions | 12 Months Ended |
Dec. 31, 2015 | |
Related Party Transactions [Abstract] | |
RELATED PARTY TRANSACTIONS | RELATED PARTY TRANSACTIONS In the normal course of business, the Ameren Companies have engaged in, and may in the future engage in, affiliate transactions. These transactions primarily consist of natural gas and power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between affiliates are reported as intercompany transactions on their financial statements, but are eliminated in consolidation for Ameren’s financial statements. Below are the material related party agreements. Electric Power Supply Agreements Ameren Illinois must acquire capacity and energy sufficient to meet its obligations to customers. Ameren Illinois uses periodic RFP processes that are administered by the IPA and approved by the ICC, to contract capacity and energy on behalf of its customers. Ameren Missouri participates in the RFP process and has been a winning supplier for certain periods. Capacity Supply Agreements In 2010, Ameren Missouri contracted to supply a portion of Ameren Illinois’ capacity requirements for less than $1 million for the period from June 1, 2010, through May 31, 2013. In a procurement event in 2012, Ameren Missouri contracted to supply a portion of Ameren Illinois' capacity requirements for $1 million and $3 million for the 12 months ending May 31, 2014, and 2015, respectively. In a procurement event in 2015, Ameren Missouri contracted to supply a portion of Ameren Illinois' capacity requirements for $15 million for the 12 months ending May 31, 2017. Energy Swaps and Energy Products As a result of an IPA procurement event in 2011, Ameren Missouri and Ameren Illinois entered into energy product agreements by which Ameren Missouri agreed to sell and Ameren Illinois agreed to purchase approximately 40,800 megawatthours at approximately $29 per megawatthour during the 12 months ended May 31, 2013, and approximately 40,800 megawatthours at approximately $28 per megawatthour during the 12 months ended May 31, 2014. The energy product agreements for the period ended May 31, 2013, were for off-peak hours only. As a result of an IPA procurement event in 2014, Ameren Missouri and Ameren Illinois entered into energy product agreements by which Ameren Missouri agreed to sell and Ameren Illinois agreed to purchase approximately 168,400 megawatthours at approximately $ 51 per megawatthour during the period of January 1, 2015, through February 28, 2017. As a result of an IPA procurement event in April 2015, Ameren Missouri and Ameren Illinois entered into energy product agreements by which Ameren Missouri agreed to sell and Ameren Illinois agreed to purchase 667,000 megawatthours at an average price of $36 per megawatthour during the period of June 1, 2015, through June 30, 2017. Also in September 2015, Ameren Missouri and Ameren Illinois entered into energy product agreements by which Ameren Missouri agreed to sell and Ameren Illinois agreed to purchase 339,000 megawatthours at an average price of $38 per megawatthour during the period of November 1, 2015, through May 31, 2018. Interconnection and Transmission Agreements Ameren Missouri and Ameren Illinois are parties to an interconnection agreement for the use of their respective transmission lines and other facilities for the distribution of power. These agreements have no contractual expiration date, but may be terminated by either party with three years’ notice. Support Services Agreements Ameren Services provides support services to its affiliates. The costs of support services, including wages, employee benefits, professional services, and other expenses, are based on, or are an allocation of, actual costs incurred. The support services agreement can be terminated at any time by the mutual agreement of Ameren Services and that affiliate or by either party with 60 days' notice before the end of a calendar year. In addition, Ameren Missouri and Ameren Illinois provide affiliates, primarily Ameren Services, with access to their facilities for administrative purposes. The costs of the rent and facility services are based on, or are an allocation of, actual costs incurred. Separately, Ameren Missouri and Ameren Illinois provide storm-related and miscellaneous support services to each other on an as-needed basis. Transmission Services Ameren Illinois takes transmission service from MISO for the retail load it serves in the AMIL pricing zone. ATXI is one of the transmission owners in the AMIL pricing zone. Accordingly, ATXI receives transmission payments from Ameren Illinois through the MISO billing process. Money Pool See Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings for a discussion of affiliate borrowing arrangements. Collateral Postings Under the terms of the Illinois power procurement agreements entered into through RFP processes administered by the IPA, suppliers must post collateral under certain market conditions to protect Ameren Illinois in the event of nonperformance. The collateral postings are unilateral, which means that only the suppliers can be required to post collateral. Therefore, Ameren Missouri, as a winning supplier in the RFP process, may be required to post collateral. As of December 31, 2015 and 2014 , there were no collateral postings required of Ameren Missouri related to the Illinois power procurement agreements. Tax Allocation Agreement See Note 1 – Summary of Significant Accounting Policies for a discussion of the tax allocation agreement. At December 31, 2015 and 2014, Ameren Missouri accrued capital contributions from Ameren (parent) of $38 million and $9 million , respectively, pursuant to the tax allocation agreement. The following table presents the impact on Ameren Missouri and Ameren Illinois of related party transactions for the years ended December 31, 2015 , 2014 , and 2013 . It is based primarily on the agreements discussed above and the money pool arrangements discussed in Note 4 – Short-term Debt and Liquidity. Agreement Income Statement Line Item Ameren Missouri Ameren Illinois Ameren Missouri power supply agreements Operating Revenues 2015 $ 15 $ (a) with Ameren Illinois 2014 5 (a) 2013 3 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2015 25 4 rent and facility services 2014 21 2 2013 21 1 Ameren Missouri and Ameren Illinois Operating Revenues 2015 2 (b) miscellaneous support services 2014 1 (b) 2013 1 3 Total Operating Revenues 2015 $ 42 $ 4 2014 27 2 2013 25 4 Ameren Illinois power supply Purchased Power 2015 $ (a) $ 15 agreements with Ameren Missouri 2014 (a) 5 2013 (a) 3 Ameren Illinois transmission Purchased Power 2015 (a) 2 services with ATXI 2014 (a) 2 2013 (a) 2 Total Purchased Power 2015 $ (a) $ 17 2014 (a) 7 2013 (a) 5 Ameren Services support services Other Operations and 2015 $ 131 $ 119 agreement Maintenance 2014 124 109 2013 116 93 Total Other Operations and 2015 $ 131 $ 119 Maintenance Expenses 2014 124 109 2013 116 93 Money pool borrowings (advances) Interest (Charges) 2015 $ (b) $ (b) Income 2014 (b) (b) 2013 (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies
Commitments And Contingencies | 12 Months Ended |
Dec. 31, 2015 | |
Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES We are involved in legal, tax, and regulatory proceedings before various courts, regulatory commissions, authorities, and governmental agencies with respect to matters that arise in the ordinary course of business, some of which involve substantial amounts of money. We believe that the final disposition of these proceedings, except as otherwise disclosed in these notes to our financial statements, will not have a material adverse effect on our results of operations, financial position, or liquidity. See also Note 1 – Summary of Significant Accounting Policies, Note 2 – Rate and Regulatory Matters, Note 10 – Callaway Energy Center, and Note 14 – Related Party Transactions in this report. Callaway Energy Center The following table presents insurance coverage at Ameren Missouri’s Callaway energy center at December 31, 2015 . The property coverage and the nuclear liability coverage must be renewed on April 1 and January 1, respectively, of each year. Type and Source of Coverage Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers $ 375 $ — Pool participation 13,114 (a) 127 (b) $ 13,489 (c) $ 127 Property damage: Nuclear Electric Insurance Limited $ 2,750 (d) $ 27 (e) European Mutual Association for Nuclear Insurance 500 (f) — $ 3,250 $ 27 Replacement power: Nuclear Electric Insurance Limited $ 490 (g) $ 10 (e) (a) Provided through mandatory participation in an industrywide retrospective premium assessment program. (b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $375 million in the event of an incident at any licensed United States commercial reactor, payable at $19 million per year. (c) Limit of liability for each incident under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended. A company could be assessed up to $127 million per incident for each licensed reactor it operates, with a maximum of $19 million per incident to be paid in a calendar year for each reactor. This limit is subject to change to account for the effects of inflation and changes in the number of licensed reactors. (d) NEIL provides $2.25 billion in property damage, decontamination, and premature decommissioning insurance for both radiation and nonradiation events. An additional $500 million is provided for radiation events only for a total of $2.75 billion . (e) All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. (f) European Mutual Association for Nuclear Insurance provides $500 million in excess of the $2.75 billion and $2.25 billion property coverage for radiation and nonradiation events, respectively, provided by NEIL. (g) Provides replacement power cost insurance in the event of a prolonged accidental outage. Weekly indemnity is up to $4.5 million for 52 weeks, which commences after the first twelve weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter, for a total not exceeding the policy limit of $490 million . Nonradiation events are sub-limited to $328 million . The Price-Anderson Act is a federal law that limits the liability for claims from an incident involving any licensed United States commercial nuclear energy center. The limit is based on the number of licensed reactors. The limit of liability and the maximum potential annual payments are adjusted at least every five years for inflation to reflect changes in the Consumer Price Index. The most recent five-year inflationary adjustment became effective in September 2013. Owners of a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by the Price-Anderson Act. Losses resulting from terrorist attacks on nuclear facilities are covered under NEIL’s policies, subject to an industrywide aggregate policy coverage limit of $3.24 billion within a 12-month period, or $ 1.83 billion for events not involving radiation contamination. If losses from a nuclear incident at the Callaway energy center exceed the limits of, or are not covered by, insurance or if coverage is unavailable, Ameren Missouri is at risk for any uninsured losses. If a serious nuclear incident were to occur, it could have a material adverse effect on Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. Leases We lease various facilities, office equipment, plant equipment, and rail cars under capital and operating leases. The following table presents our lease obligations at December 31, 2015 : 2016 2017 2018 2019 2020 After 5 Years Total Ameren: (a) Minimum capital lease payments (b) $ 33 $ 33 $ 32 $ 32 $ 32 $ 329 $ 491 Less amount representing interest 27 27 26 25 25 73 203 Present value of minimum capital lease payments $ 6 $ 6 $ 6 $ 7 $ 7 $ 256 $ 288 Operating leases (c) 14 13 12 12 11 30 92 Total lease obligations $ 20 $ 19 $ 18 $ 19 $ 18 $ 286 $ 380 Ameren Missouri: Minimum capital lease payments (b) $ 33 $ 33 $ 32 $ 32 $ 32 $ 329 $ 491 Less amount representing interest 27 27 26 25 25 73 203 Present value of minimum capital lease payments $ 6 $ 6 $ 6 $ 7 $ 7 $ 256 $ 288 Operating leases (c) 12 11 11 11 10 29 84 Total lease obligations $ 18 $ 17 $ 17 $ 18 $ 17 $ 285 $ 372 Ameren Illinois: Operating leases (c) $ 1 $ 1 $ 1 $ 1 $ 1 $ 1 $ 6 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (b) See Properties under Part I, Item 2, and Note 3 – Property and Plant, Net, of this report for additional information. (c) Amounts related to certain land-related leases have indefinite payment periods. The annual obligations of $3 million , $2 million , and $1 million for Ameren, Ameren Missouri, and Ameren Illinois for these items are included in the 2016 through 2020 columns, respectively. The following table presents total rental expense included in operating expenses for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren (a) $ 36 $ 37 $ 32 Ameren Missouri 34 32 29 Ameren Illinois 28 25 21 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Other Obligations To supply a portion of the fuel requirements of our energy centers, we have entered into various long-term commitments for the procurement of coal, natural gas, nuclear fuel, and methane gas. We also have entered into various long-term commitments for purchased power and natural gas for distribution. The table below presents our estimated fuel, purchased power, and other commitments for fuel at December 31, 2015 . Ameren’s and Ameren Missouri’s purchased power commitments include a 102-megawatt power purchase agreement with a wind farm operator, which expires in 2024. Ameren’s and Ameren Illinois’ purchased power commitments include the Ameren Illinois power purchase agreements entered into as part of the IPA-administered power procurement process. Included in the Other column are minimum purchase commitments under contracts for equipment, design and construction, and meter reading services at December 31, 2015 . Coal Natural Gas (a) Nuclear Fuel Purchased Power (b) Methane Gas Other Total Ameren: (c) 2016 $ 664 $ 249 $ 51 $ 241 $ 3 $ 115 $ 1,323 2017 685 190 46 147 4 73 1,145 2018 204 127 68 72 5 55 531 2019 110 89 24 58 5 56 342 2020 — 43 51 58 6 57 215 Thereafter — 60 108 539 71 350 1,128 Total $ 1,663 $ 758 $ 348 $ 1,115 $ 94 $ 706 $ 4,684 Ameren Missouri: 2016 $ 664 $ 46 $ 51 $ 23 $ 3 $ 46 $ 833 2017 685 36 46 23 4 32 826 2018 204 24 68 23 5 28 352 2019 110 14 24 23 5 29 205 2020 — 10 51 23 6 30 120 Thereafter — 23 108 84 71 183 469 Total $ 1,663 $ 153 $ 348 $ 199 $ 94 $ 348 $ 2,805 Ameren Illinois: 2016 $ — $ 203 $ — $ 218 $ — $ 31 $ 452 2017 — 154 — 124 — 25 303 2018 — 103 — 49 — 24 176 2019 — 75 — 35 — 27 137 2020 — 33 — 35 — 27 95 Thereafter — 37 — 455 — 167 659 Total $ — $ 605 $ — $ 916 $ — $ 301 $ 1,822 (a) Includes amounts for generation and for distribution. (b) The purchased power amounts for Ameren and Ameren Illinois include agreements through 2032 for renewable energy credits with various renewable energy suppliers. The agreements contain a provision that allows Ameren Illinois to reduce the quantity purchased in the event that Ameren Illinois would not be able to recover the costs associated with the renewable energy credits. (c) Includes amounts for Ameren registrant and nonregistrant subsidiaries. Environmental Matters We are subject to various environmental laws and regulations enforced by federal, state, and local authorities. From the beginning phases of siting and development to the operation of electric generation, transmission, and distribution facilities and natural gas storage, transmission, and distribution facilities, our activities involve compliance with diverse environmental laws and regulations. These laws and regulations address emissions, discharges to water, water usage, impacts to air, land, and water, and chemical and waste handling. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing or modified facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures. The EPA has promulgated several environmental regulations that will have a significant impact on the electric utility industry. Over time, compliance with these regulations could be costly for certain companies, including Ameren Missouri, that operate coal-fired power plants. Significant new rules include the regulation of CO 2 emissions from existing power plants through the Clean Power Plan and from new power plants through the revised NSPS; the CSAPR, which requires further reductions of SO 2 emissions and NO x emissions from power plants; a regulation governing management and storage of CCR; the MATS, which require reduction of emissions of mercury, toxic metals, and acid gases from power plants; revised NSPS for particulate matter, SO 2 , and NO x emissions from new sources; new effluent standards applicable to wastewater discharges from power plants and new regulations under the Clean Water Act that could require significant capital expenditures, such as modifications to water intake structures or new cooling towers at Ameren Missouri’s energy centers. The EPA also periodically reviews and revises national ambient air quality standards, including those standards associated with emissions from power plants, such as particulate matter, ozone, SO 2 and NO x . Certain of these new regulations are being or are likely to be challenged through litigation, so their ultimate implementation, as well as the timing of any such implementation, is uncertain. Although many details of future regulations are unknown, individually or the combined effects of new environmental regulations could result in significant capital expenditures and increased operating costs for Ameren and Ameren Missouri. Compliance with all of these environmental laws and regulations could be prohibitively expensive, result in the closure or alteration of the operation of some of Ameren Missouri’s energy centers, or require capital investment. Ameren and Ameren Missouri expect that these costs would be recoverable through rates, subject to MoPSC prudence review, but the nature and timing of costs could result in regulatory lag. Ameren Missouri's current plan for compliance with existing environmental regulations for air emissions includes burning ultra-low-sulfur coal and installing new or optimizing existing pollution control equipment. Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $600 million to $700 million in the aggregate from 2016 through 2020 in order to comply with existing environmental regulations. Ameren Missouri may be required to install additional air emissions controls within the next six to 10 years. This estimate includes our capital expenditures required for the CCR regulations that were published in 2015, the rule applicable to cooling water intake structures at existing power plants under the Clean Water Act, and the effluent limitation guidelines applicable to steam electric generating units under the Clean Water Act, all of which are discussed below. These estimates do not include the impacts of the Clean Power Plan discussed below. Considerable uncertainty remains in these estimates. The actual amount of capital expenditures required to comply with existing environmental regulations may vary substantially from the above estimate due to uncertainty as to the precise compliance strategies that will be used and their ultimate cost, among other things. The following sections describe the more significant new environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. Clean Air Act Federal and state laws require significant reductions in SO 2 and NO x through either emission source reductions or the use and retirement of emission allowances. The CSAPR became effective in 2015. There will be further emission reduction requirements in 2017 and potentially more in subsequent years. To achieve compliance with CSAPR, Ameren Missouri burns ultra-low-sulfur coal and operates two scrubbers at its Sioux energy center. Ameren Missouri does not expect to make additional capital investments to comply with the current CSAPR requirements. However, Ameren Missouri expects to incur additional costs as it lowers its emissions at one or more of its energy centers to comply with the CSAPR in future years. These higher costs are expected to be collected from customers through the FAC or higher base rates. In December 2011, the EPA issued the MATS under the Clean Air Act, which requires reductions in emissions of mercury and other hazardous air pollutants, such as acid gases, trace metals, and hydrogen chloride. The MATS do not require a specific control technology to achieve the emission reductions. The MATS apply to each unit at a coal-fired power plant. However, in certain cases, compliance can be achieved by averaging emissions from similar units at the same power plant. Compliance was required by April 2015 or, with a case-by-case extension, by April 2016. All of Ameren Missouri's coal-fired power plants will be in compliance before the required due dates. As part of Ameren Missouri's compliance plan, the Meramec energy center will burn natural gas at two of its units beginning in April 2016, thereby excluding such units from the MATS. In addition, Ameren Missouri is incurring additional costs to comply with the MATS. These higher costs are being collected from customers through the FAC or higher base rates. CO 2 Emissions Standards The Clean Power Plan, which sets forth CO 2 emissions standards applicable to existing power plants, was issued by the EPA but stayed by the United States Supreme Court pending the outcome of various appeals, as discussed below. If the Clean Power Plan is ultimately upheld as issued, Ameren Missouri expects to incur increased fuel and operating costs, and make new or accelerated capital expenditures, in addition to the costs of making modifications to existing operations in order to achieve compliance. The Clean Power Plan required Missouri and Illinois to reduce CO 2 emissions from power plants within their states significantly below 2005 levels by 2030. The rule contains interim compliance periods commencing in 2022 that require each state to demonstrate progress in achieving its CO 2 reduction target. Ameren is evaluating the Clean Power Plan's potential impacts to its operations, including those related to electric system reliability, and to its level of investment in customer energy efficiency programs, renewable energy, and other forms of generation investment. Significant uncertainty exists regarding the impact of the Clean Power Plan, as its implementation will depend upon plans to be developed by the states. Numerous legal challenges are pending, which could result in the rule being declared invalid or the nature and timing of CO 2 emissions reductions being revised. In February 2016, the United States Supreme Court stayed the Clean Power Plan and all implementation requirements until such time as legal appeals are concluded. The District of Columbia Circuit Court of Appeals has scheduled hearings for June 2016 on the legality of the rule. A decision by the District of Columbia Circuit Court of Appeals is expected to be issued later this year and additional appeals before the United States Supreme Court are likely. Appeals are not expected to conclude prior to 2018. We cannot predict the outcome of such legal challenges or their impact on our results of operations, financial position, or liquidity. If the rule is ultimately upheld and implemented in substantially similar form to the rule when issued, compliance measures could result in the closure or alteration of the operation of some of Ameren Missouri’s coal and natural-gas-fired energy centers, which could result in increased operating costs. Ameren Missouri expects substantially all of these increased costs to be recoverable, subject to MoPSC prudence review, through higher rates to customers, which could be significant. Also, in August 2015, the EPA issued final regulations that set CO 2 emissions standards for new power plants. These new standards establish separate emissions limits for new natural-gas-fired combined cycle plants and new coal-fired plants. Federal and state legislation or regulations that mandate limits on the emission of CO 2 may result in significant increases in capital expenditures and operating costs, which could lead to increased liquidity needs and higher financing costs. Mandatory limits on the emission of CO 2 could increase costs for Ameren Missouri’s customers or have a material adverse effect on Ameren's and Ameren Missouri's results of operations, financial position, and liquidity if regulators delay or deny recovery in rates of these compliance costs. The cost of Ameren Illinois’ purchased power and gas purchased for resale could increase. However, Ameren Illinois expects these costs would be recovered from customers with no material adverse effect on its results of operations, financial position, or liquidity. Ameren's and Ameren Missouri's earnings might benefit from increased investment to comply with CO 2 emission limitations to the extent that the investments are reflected and recovered on a timely basis in rates charged to customers. NSR and Clean Air Litigation In January 2011, the Department of Justice, on behalf of the EPA, filed a complaint against Ameren Missouri in the United States District Court for the Eastern District of Missouri. The EPA's complaint, as amended in October 2013, alleges that in performing projects at its Rush Island coal-fired energy center in 2007 and 2010, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. Ameren Missouri anticipates that a trial of this case could occur as early as 2016. Ameren Missouri believes its defenses are meritorious and is defending itself vigorously. However, there can be no assurances that it will be successful in its efforts. The ultimate resolution of this matter could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. A resolution of this matter could result in increased capital expenditures for the installation of pollution control equipment and increased operations and maintenance expenses. We are unable to predict the ultimate resolution of these matters or the costs that might be incurred. Clean Water Act In August 2014, the EPA issued its final rule applicable to cooling water intake structures at existing power plants. The rule requires a case-by-case evaluation and plan for reducing aquatic organisms impinged on the facility’s intake screens or entrained through the plant's cooling water system. All of Ameren Missouri’s coal-fired and nuclear energy centers are subject to this rule. Each of Ameren Missouri’s affected energy centers will become subject to the revised limitations when it renews its water discharge permit. These permits are scheduled to be renewed between 2018 and 2023. The rule could have an adverse effect on Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity if its implementation requires the installation of cooling towers or extensive modifications to the cooling water systems at our energy centers and if those investments are not recovered on a timely basis in electric rates charged to Ameren Missouri's customers. In September 2015, the EPA issued its final rule under the Clean Water Act to revise the effluent limitation guidelines applicable to steam electric generating units. Effluent limitation guidelines are national standards for water discharges that are based on the effectiveness of available control technology. The EPA's rule prohibits effluent discharges of certain, but not all, waste streams and imposes more stringent limitations on certain components in water discharges from power plants. All of Ameren Missouri’s coal-fired energy centers are subject to this rule and its implementation will be consistent with the water discharge permit process described above beginning as early as 2018. Ameren Missouri is evaluating the final rule, which became effective in January 2016, and the possible effects on its operations. Ash Management In 2015, the EPA issued regulations regarding the management and disposal of CCR, that will affect future CCR disposal and handling costs at Ameren Missouri's energy centers. The regulations allow for the management of CCR as a solid waste, as well as for its continued beneficial uses, such as recycling, which could reduce the amount to be disposed. The regulations also establish criteria regarding the structural integrity, location, and operation of CCR impoundments and landfills. They require groundwater monitoring and closure of impoundments if the groundwater standards are not achieved. During 2015, Ameren and Ameren Missouri recorded an increase to their AROs associated with CCR storage facilities and accelerated the closure of certain CCR storage facilities at its energy centers as a result of the new regulations. Ameren Missouri plans to close these CCR storage facilities between 2018 and 2023. See Note 1 – Summary of Significant Accounting Policies in this report for additional information. Ameren Missouri's capital expenditure plan includes the cost of constructing landfills as part of its environmental compliance plan. The new regulations do not apply to ash ponds at plants no longer in operation, such as Ameren’s Meredosia and Hutsonville energy centers. Remediation The Ameren Companies are involved in a number of remediation actions to clean up sites affected by hazardous substances, as required by federal and state law. Such laws require that responsible parties fund remediation actions regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site. Ameren Missouri and Ameren Illinois have each been identified by federal or state governments as a potentially responsible party at several contaminated sites. As of December 31, 2015 , Ameren Illinois owned or was otherwise responsible for 44 former MGP sites in Illinois, which are in various stages of investigation, evaluation, remediation, and closure. Ameren Illinois estimates it could substantially conclude remediation efforts by 2025. The ICC allows Ameren Illinois to recover remediation and litigation costs associated with its former MGP sites from its electric and natural gas utility customers through environmental adjustment rate riders. Costs are subject to annual prudence review by the ICC. As of December 31, 2015 , Ameren Illinois estimated the obligation related to these former MGP sites at $232 million to $313 million . Ameren and Ameren Illinois recorded a liability of $232 million to represent their estimated minimum obligation for these sites, as no other amount within the range was a better estimate. The scope and extent to which these former MGP sites are remediated may increase as remediation efforts continue. Considerable uncertainty remains in these estimates, as many factors can influence the ultimate actual costs, including site-specific unanticipated underground structures, the degree to which groundwater is encountered, regulatory changes, local ordinances, and site accessibility. The actual costs may vary substantially from these estimates. Ameren Illinois formerly used an off-site landfill, which Ameren Illinois did not own, in connection with the operation of a previously owned energy center. Ameren Illinois could be required to perform certain maintenance activities at that landfill, which is now closed. As of December 31, 2015 , Ameren Illinois estimated the obligation related to this site at $0.5 million to $6 million . Ameren Illinois recorded a liability of $0.5 million to represent its estimated minimum obligation for this site, as no other amount within the range was a better estimate. Ameren Illinois is also responsible for the cleanup of some underground storage tanks and a water treatment plant in Illinois. As of December 31, 2015 , Ameren Illinois recorded a liability of $0.7 million to represent its best estimate of the obligation for these sites. In 2008, the EPA issued an administrative order to Ameren Missouri pertaining to a former coal tar distillery in St. Louis, Missouri, operated by Koppers Company or its predecessor and successor companies. While Ameren Missouri is the current owner of the site, it did not conduct any of the manufacturing operations involving coal tar or its byproducts. Ameren Missouri, along with two other potentially responsible parties, have completed site investigation activities and have submitted their findings to the EPA. As of December 31, 2015 , Ameren Missouri estimated its obligation at $2 million to $5 million . Ameren Missouri recorded a liability of $2 million to represent its estimated minimum obligation, as no other amount within the range was a better estimate. Ameren Missouri also participated in the investigation of several sites located in Sauget, Illinois. In 2000, the EPA notified Ameren Missouri and numerous other companies, including Solutia, Inc., that former landfills and lagoons at those sites may contain soil and groundwater contamination. These sites are known as Sauget Area 2. From about 1926 until 1976, Ameren Missouri operated an energy center adjacent to Sauget Area 2. Ameren Missouri currently owns a parcel of property at Sauget Area 2 that was once used as a landfill. In December 2013, the EPA issued its record of decision for Sauget Area 2 approving the investigation and the remediation alternatives recommended by the potentially responsible parties. Further negotiation among the potentially responsible parties will determine how to fund the implementation of the EPA-approved cleanup remedies. As of December 31, 2015 , Ameren Missouri estimated its obligation related to Sauget Area 2 at $1 million to $2.5 million . Ameren Missouri recorded a liability of $1 million to represent its estimated minimum obligation, as no other amount within the range was a better estimate. In December 2012, Ameren Missouri signed an administrative order with the EPA and agreed to investigate soil and groundwater conditions at an Ameren Missouri-owned substation in St. Charles, Missouri. As of December 31, 2015 , Ameren Missouri estimated and recorded a $0.6 million liability related to the site. Although monitoring will continue for some time, no significant additional remediation measures are anticipated. Our operations or those of our predecessor companies involve the use of, disposal of, and in appropriate circumstances, the cleanup of substances regulated under environmental laws. We are unable to determine whether such practices will result in future environmental commitments or will affect our results of operations, financial position, or liquidity. Pumped-storage Hydroelectric Facility Breach In December 2005, there was a breach of the upper reservoir at Ameren Missouri's Taum Sauk pumped-storage hydroelectric energy center. The breach resulted in significant flooding in the local area, which damaged a state park. Ameren Missouri had liability insurance coverage for the Taum Sauk incident, subject to certain limits and deductibles. As of December 31, 2015 , Ameren Missouri had an insurance receivable of $41 million . In February 2016, Ameren Missouri and an insurer that was providing Ameren Missouri with liability coverage on the date of the Taum Sauk incident reached a settlement that resulted in Ameren Missouri receiving $42 million . As a result of this settlement, the receivable was included in “Miscellaneous accounts and notes receivable” on Ameren’s and Ameren Missouri’s balance sheets as of December 31, 2015 whereas previously this receivable was included in “Other assets” on their respective balance sheets as of December 31, 2014. Asbestos-related Litigation Ameren, Ameren Missouri, and Ameren Illinois have been named, along with numerous other parties, in a number of lawsuits filed by plaintiffs claiming varying degrees of injury from asbestos exposure at our present or former energy centers. Most have been filed in the Circuit Court of Madison County, Illinois. The total number of defendants named in each case varies, with 75 as the average number of parties as of December 31, 2015 . Each lawsuit seeks unspecified damages that, if awarded at trial, typically would be shared among the various defendants. The following table presents the pending asbestos-related lawsuits filed against Ameren Missouri and Ameren Illinois as of December 31, 2015 : Ameren Missouri Ameren Illinois Total (a) 26 38 48 (a) Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. At December 31, 2015 , Ameren, Ameren Missouri, and Ameren Illinois had liabilities of $8 million , $3 million , and $5 million , respectively, recorded to represent their best estimates of their obligations related to asbestos claims. Ameren Illinois has a tariff rider to recover the costs of IP asbestos-related litigation claims, subject to the following terms: 90% of the cash expenditures in excess of the amount included in base electric rates is to be recovered from a trust fund that was established when Ameren acquired IP. At December 31, 2015 , the trust fund balance was $22 million , including accumulated interest. If cash expenditures are less than the amount in base rates, Ameren Illinois will contribute 90% of the difference to the trust fund. Once the trust fund is depleted, 90% of allowed cash expenditures in excess of base rates will be recovered through charges assessed to customers under the tariff rider. The rider will permit recovery from electric customers within IP’s historical service territory. Ameren Missouri Municipal Taxes The cities of Creve Coeur and Winchester, Missouri, on behalf of themselves and other municipalities in Ameren Missouri’s service area, filed a class action lawsuit in November 2011 against Ameren Missouri in the Circuit Court of St. Louis County, Missouri. The lawsuit alleges that Ameren Missouri failed to collect and pay gross receipts taxes or license fees on certain revenues. Ameren and Ameren Missouri recorded immaterial liabilities on their respective balance sheets as of December 31, 2015, representing their estimate of taxes and fees due as a result of this lawsuit. The ultimate resolution of any unpaid municipal tax or fees could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. Ameren Missouri believes its defenses are meritorious and is defending itself vigorously; however, there can be no assurances that Ameren Missouri will be successful in its efforts. |
Divestiture Transactions and Di
Divestiture Transactions and Discontinued Operations | 12 Months Ended |
Dec. 31, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | |
DIVESTITURE TRANSACTIONS AND DISCONTINUED OPERATIONS | NOTE 16 – DIVESTITURE TRANSACTIONS AND DISCONTINUED OPERATIONS On December 2, 2013, Ameren completed the divestiture of New AER to IPH in accordance with the transaction agreement between Ameren and IPH dated March 14, 2013, as amended by a letter agreement dated December 2, 2013. Pursuant to that agreement, in 2015, Ameren paid $25 million related to a previously-recorded liability and concluded its obligations to provide credit support to New AER with no resulting additional impact to its results of operations. The transaction agreement with IPH, as amended, provides that if the Elgin, Gibson City, and Grand Tower gas-fired energy centers are subsequently sold by Medina Valley and if Medina Valley receives additional proceeds from such sale, Medina Valley will pay Genco any proceeds from such sale, net of taxes and other expenses, in excess of the $137.5 million previously paid to Genco. On January 31, 2014, Medina Valley completed the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital for a total purchase price of $168 million . The agreement with Rockland Capital required a portion of the purchase price to be held in escrow until January 31, 2016, to fund certain indemnity obligations, if any, of Medina Valley. Medina Valley received the escrow balance from Rockland Capital and expects to pay Genco its portion of that escrow balance during the first quarter of 2016. Discontinued Operations Presentation All matters related to the final tax basis of New AER and the related tax benefit resulting from the divested merchant generation business have been resolved with the completion of the IRS audit for 2013. During 2015, based on the completion of the IRS audit, Ameren removed a reserve for unrecognized tax benefits recorded in 2013 and recognized a tax benefit from discontinued operations. See Note 13 – Income Taxes for additional information regarding the Ameren Companies’ uncertain tax positions. The following table presents the components of discontinued operations in Ameren's consolidated statement of income (loss) for the years ended December 31, 2015, 2014, and 2013: Year ended 2015 2014 2013 Operating revenues $ — $ 1 $ 1,037 Operating benefits (expenses) 1 (2 ) (1,207 ) (a) Operating income (loss) 1 (1 ) (170 ) Other income (loss) — — (1 ) Interest charges — — (39 ) Income (loss) before income taxes 1 (1 ) (210 ) Income tax (expense) benefit 50 — (13 ) Income (loss) from discontinued operations, net of taxes $ 51 $ (1 ) $ (223 ) (a) Includes a $201 million pretax loss on disposal relating to the New AER divestiture. The following table presents the carrying amounts of the components of assets and liabilities of Ameren's discontinued operations, which consist primarily of AROs and related deferred income tax assets associated with the abandoned Meredosia and Hutsonville energy centers, at December 31, 2015 and 2014: December 31, 2015 December 31, 2014 Assets of discontinued operations Accumulated deferred income taxes, net $ 14 $ 15 Total assets of discontinued operations $ 14 $ 15 Liabilities of discontinued operations Accounts payable and other current obligations $ 1 $ 1 Asset retirement obligations (a) 28 32 Total liabilities of discontinued operations $ 29 $ 33 (a) Ameren is demolishing the Hutsonville energy center and expects to demolish the Meredosia energy center beginning in 2016. |
Segment Information
Segment Information | 12 Months Ended |
Dec. 31, 2015 | |
Segment Reporting Information, Profit (Loss) [Abstract] | |
SEGMENT INFORMATION | SEGMENT INFORMATION Ameren has two reportable segments: Ameren Missouri and Ameren Illinois. Ameren Missouri and Ameren Illinois each have one reportable segment. The Ameren Missouri segment for both Ameren and Ameren Missouri includes all the operations of Ameren Missouri as described in Note 1 – Summary of Significant Accounting Policies. The Ameren Illinois segment for both Ameren and Ameren Illinois consists of all of the operations of Ameren Illinois as described in Note 1 – Summary of Significant Accounting Policies. The category called Other primarily includes Ameren parent company activities, Ameren Services, and ATXI. The Other category also includes certain corporate activities previously included in the Merchant Generation segment. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. The following table presents information about the reported revenues and specified items reflected in Ameren’s net income attributable to Ameren common shareholders and capital expenditures from continuing operations for the years ended December 31, 2015 , 2014 , and 2013 , and total assets in continuing operations as of December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Other Intersegment Eliminations Consolidated 2015 External revenues $ 3,566 $ 2,462 $ 70 $ — $ 6,098 Intersegment revenues 43 4 2 (49 ) — Depreciation and amortization 492 295 9 — 796 Interest and dividend income 28 12 1 — 41 Interest charges 219 131 5 — 355 Income taxes 209 127 27 — 363 Net income attributable to Ameren common shareholders from continuing operations 352 214 13 — 579 Capital expenditures 622 918 377 (a) — 1,917 Total assets (c) 13,851 8,903 1,139 (267 ) 23,626 (b) 2014 External revenues $ 3,526 $ 2,496 $ 31 $ — $ 6,053 Intersegment revenues 27 2 2 (31 ) — Depreciation and amortization 473 263 9 — 745 Interest and dividend income 28 7 2 — 37 Interest charges 211 112 18 — 341 Income taxes 229 143 5 — 377 Net income (loss) attributable to Ameren common shareholders from continuing operations 390 201 (4 ) — 587 Capital expenditures 747 835 203 (a) — 1,785 Total assets (c) 13,474 8,204 799 (203 ) 22,274 (b) 2013 External revenues $ 3,516 $ 2,307 $ 15 $ — $ 5,838 Intersegment revenues 25 4 2 (31 ) — Depreciation and amortization 454 243 9 — 706 Interest and dividend income 27 2 1 — 30 Interest charges 210 143 45 — 398 Income taxes (benefit) 242 110 (41 ) — 311 Net income (loss) attributable to Ameren common shareholders from continuing operations 395 160 (43 ) — 512 Capital expenditures 648 701 30 (a) — 1,379 Total assets (c) 12,867 7,397 711 (233 ) 20,742 (b) (a) Includes the elimination of intercompany transfers. (b) Excludes total assets from discontinued operations of $14 million , $15 million , and $165 million as of December 31, 2015 , 2014 , and 2013 , respectively. (c) Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs and balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. |
Selected Quarterly Information
Selected Quarterly Information | 12 Months Ended |
Dec. 31, 2015 | |
Selected Quarterly Financial Information [Abstract] | |
SELECTED QUARTERLY INFORMATION | SELECTED QUARTERLY INFORMATION (Unaudited) (In millions, except per share amounts) Ameren 2015 2014 Quarter ended (a) March 31 June 30 September 30 December 31 March 31 June 30 September 30 December 31 Operating revenues $ 1,556 $ 1,401 $ 1,833 $ 1,308 $ 1,594 $ 1,419 $ 1,670 $ 1,370 Operating income 256 237 626 140 246 322 561 125 Net income 110 151 345 30 98 150 295 49 Net income attributable to Ameren common shareholders – continuing operations $ 108 $ 98 $ 343 $ 30 $ 97 $ 150 $ 294 $ 46 Net income (loss) attributable to Ameren common shareholders – discontinued operations — 52 — (1 ) (1 ) (1 ) (1 ) 2 Net income attributable to Ameren common shareholders $ 108 $ 150 $ 343 $ 29 $ 96 $ 149 $ 293 $ 48 Earnings per common share – basic – continuing operations $ 0.45 $ 0.40 $ 1.42 $ 0.12 $ 0.40 $ 0.62 $ 1.21 $ 0.19 Earnings (loss) per common share – basic – discontinued operations — 0.21 — — — (0.01 ) — 0.01 Earnings per common share – basic $ 0.45 $ 0.61 $ 1.42 $ 0.12 $ 0.40 $ 0.61 $ 1.21 $ 0.20 Earnings per common share – diluted – continuing operations $ 0.45 $ 0.40 $ 1.41 $ 0.12 $ 0.40 $ 0.62 $ 1.20 $ 0.19 Earnings (loss) per common share – diluted – discontinued operations — 0.21 — — — (0.01 ) — 0.01 Earnings per common share – diluted $ 0.45 $ 0.61 $ 1.41 $ 0.12 $ 0.40 $ 0.61 $ 1.20 $ 0.20 (a) The sum of quarterly amounts, including per share amounts, may not equal amounts reported for year-to-date periods. This is because of the effects of rounding and the changes in the number of weighted-average diluted shares outstanding each period. Ameren Missouri Quarter ended Operating Revenues Operating Income Net Income (Loss) Net Income (Loss) Available to Common Shareholder March 31, 2015 $ 800 $ 115 $ 42 $ 41 March 31, 2014 817 119 48 47 June 30, 2015 884 146 62 61 June 30, 2014 900 243 127 126 September 30, 2015 1,171 423 240 239 September 30, 2014 1,097 394 223 222 December 31, 2015 754 58 11 11 December 31, 2014 739 29 (5 ) (5 ) Ameren Illinois Quarter ended Operating Revenues Operating Income Net Income Net Income Available to Common Shareholder March 31, 2015 $ 745 $ 120 $ 54 $ 53 March 31, 2014 774 120 54 53 June 30, 2015 513 83 32 31 June 30, 2014 519 75 29 28 September 30, 2015 655 189 98 98 September 30, 2014 572 158 75 75 December 31, 2015 553 74 33 32 December 31, 2014 633 97 46 45 |
Schedule I - Condensed Financia
Schedule I - Condensed Financial Information Of Parent | 12 Months Ended |
Dec. 31, 2015 | |
Condensed Financial Information of Parent Company Only Disclosure [Abstract] | |
Condensed Financial Information Of Parent | SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (In millions) 2015 2014 2013 Operating revenues $ — $ — $ — Operating expenses 14 11 26 Operating loss (14 ) (11 ) (26 ) Equity in earnings of subsidiaries 600 607 546 Interest income from affiliates 6 3 3 Total other income (expense), net (5 ) 2 (5 ) Interest charges 3 16 42 Income tax (benefit) 5 (2 ) (36 ) Net Income Attributable to Ameren Common Shareholders – Continuing Operations 579 587 512 Net Income (Loss) Attributable to Ameren Common Shareholders – Discontinued Operations 51 (1 ) (223 ) Net Income Attributable to Ameren Common Shareholders $ 630 $ 586 $ 289 Net Income Attributable to Ameren Common Shareholders – Continuing Operations $ 579 $ 587 $ 512 Other Comprehensive Income, Net of Taxes: Pension and other postretirement benefit plan activity, net of income taxes (benefit) of $3, $(7), and $16, respectively 6 (12 ) 30 Comprehensive Income from Continuing Operations Attributable to Ameren Common Shareholders 585 575 542 Net Income (Loss) Attributable to Ameren Common Shareholders – Discontinued Operations 51 (1 ) (223 ) Other Comprehensive Loss from Discontinued Operations, Net of Income taxes — — (19 ) Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Common Shareholders 51 (1 ) (242 ) Comprehensive Income Attributable to Ameren Common Shareholders $ 636 $ 574 $ 300 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (In millions) December 31, 2015 December 31, 2014 Assets: Cash and cash equivalents $ — $ 1 Advances to money pool — 55 Accounts receivable – affiliates 53 28 Notes receivable – affiliates — 94 Miscellaneous accounts and notes receivable 3 39 Other current assets 9 14 Total current assets 65 231 Investments in subsidiaries – continuing operations 7,231 6,680 Investment in subsidiary – discontinued operations (4 ) (4 ) Note receivable – ATXI 290 100 Accumulated deferred income taxes, net 426 407 Other assets 158 152 Total assets $ 8,166 $ 7,566 Liabilities and Shareholders’ Equity: Short-term debt 301 585 Borrowings from money pool 14 — Accounts payable – affiliates 75 88 Other current liabilities 22 52 Total current liabilities 412 725 Long-term debt 694 — Pension and other postretirement benefits 33 47 Other deferred credits and liabilities 81 81 Total liabilities 1,220 853 Commitments and Contingencies (Notes 4 and 5) Shareholders’ Equity: Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 242.6 2 2 Other paid-in capital, principally premium on common stock 5,616 5,617 Retained earnings 1,331 1,103 Accumulated other comprehensive loss (3 ) (9 ) Total shareholders’ equity 6,946 6,713 Total liabilities and shareholders’ equity $ 8,166 $ 7,566 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (In millions) 2015 2014 2013 Net cash flows provided by operating activities $ 537 $ 514 $ 453 Cash flows from investing activities: Money pool advances, net 55 279 (371 ) Notes receivable – affiliates, net (96 ) (134 ) (23 ) Investments in subsidiaries (509 ) (280 ) (50 ) Distributions from subsidiaries — 215 1 Proceeds from note receivable – Marketing Company 20 95 6 Contributions to note receivable – Marketing Company (8 ) (89 ) (5 ) Other (24 ) (12 ) (3 ) Net cash flows provided by (used in) investing activities (562 ) 74 (445 ) Cash flows from financing activities: Dividends on common stock (402 ) (390 ) (388 ) Short-term debt, net (284 ) 217 368 Money pool borrowings, net 14 — — Maturities of long-term debt — (425 ) — Issuances of long-term debt 700 — — Capital issuance costs (6 ) — — Other 2 — — Net cash flows provided by (used in) financing activities 24 (598 ) (20 ) Net change in cash and cash equivalents $ (1 ) $ (10 ) $ (12 ) Cash and cash equivalents at beginning of year 1 11 23 Cash and cash equivalents at end of year $ — $ 1 $ 11 Cash dividends received from consolidated subsidiaries $ 575 $ 340 $ 570 Noncash investing activity – divestiture $ — $ — $ 494 Noncash investing activity – investments in subsidiaries (38 ) (19 ) — AMEREN CORPORATION (parent company only) NOTES TO CONDENSED FINANCIAL STATEMENTS December 31, 2015 NOTE 1 – BASIS OF PRESENTATION Ameren Corporation (parent company only) is a public utility holding company that conducts substantially all of its business operations through its subsidiaries. In accordance with authoritative accounting guidance, Ameren Corporation (parent company only) has accounted for wholly owned subsidiaries using the equity method. These financial statements are presented on a condensed basis. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report for additional information. Accounting Changes and Other Matters Presentation of Debt Issuance Costs During 2015, the FASB issued authoritative accounting guidance requiring debt issuance costs to be presented as a reduction to the associated debt liability. Previously, debt issuance costs were presented in "Other assets" on Ameren Corporation's (parent company only) balance sheet. Ameren Corporation (parent company only) early adopted this standard in 2015. Retrospective application of the new guidance had no impact on Ameren Corporation's (parent company only) balance sheet at December 31, 2014. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for additional information. Balance Sheet Classification of Deferred Income Taxes During 2015, the FASB issued authoritative accounting guidance requiring all deferred tax assets and liabilities, along with any related valuation allowances, to be classified as noncurrent on the balance sheet. Previously, the current portion of deferred taxes was presented as "Current accumulated deferred income taxes, net" and the noncurrent portion of deferred taxes was presented as "Accumulated deferred income taxes, net" on Ameren Corporation's (parent company only) balance sheet. Ameren Corporation (parent company only) early adopted this standard in 2015 and applied the guidance retrospectively. At December 31, 2014, the current portion of deferred income taxes of $143 million previously presented as "Current accumulated deferred income taxes, net" on Ameren Corporation's (parent company only) balance sheet was reclassified and presented in "Accumulated deferred income taxes, net" for comparative purposes. Additional disclosures relating to the parent company financial statements are included within the combined notes under Part II, Item 8, of this report. See Note 1 – Summary of Significant Accounting Policies and Note 14 – Related Party Transactions under Part II, Item 8, of this report for information on the tax allocation agreement between Ameren Corporation (parent company only) and its subsidiaries. NOTE 2 – SHORT-TERM DEBT AND LIQUIDITY Ameren, Ameren Services, and other non-state-regulated Ameren subsidiaries have the ability, subject to Ameren parent company and applicable regulatory short-term borrowing authorizations, to access funding from the Credit Agreements and the commercial paper programs through a non-state-regulated subsidiary money pool agreement. All participants may borrow from or lend to the non-state-regulated money pool. The total amount available to pool participants from the non-state-regulated subsidiary money pool at any given time is reduced by the amount of borrowings made by participants, but is increased to the extent that the pool participants advance surplus funds to the non-state-regulated subsidiary money pool or remit funds from other external sources. The non-state-regulated subsidiary money pool was established to coordinate and to provide short-term cash and working capital for the participants. Participants receiving a loan under the non-state-regulated subsidiary money pool agreement must repay the principal amount of such loan, together with accrued interest. The rate of interest depends on the composition of internal and external funds in the non-state-regulated subsidiary money pool. Interest revenues and interest charges related to non-state-regulated money pool advances and borrowings were immaterial in 2014 and 2015. Ameren Corporation (parent company only) had a total of $36 million in guarantees outstanding primarily for ATXI that were not recorded on its December 31, 2015 balance sheet. The ATXI guarantees were issued to local governments as assurance for potential remediation of damage caused by ATXI construction. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for a description and details of short-term debt and liquidity needs of Ameren Corporation (parent company only). NOTE 3 – LONG-TERM OBLIGATIONS In November 2015, Ameren Corporation (parent company only) issued $350 million of 2.70% senior unsecured notes due November 15, 2020, with interest payable semiannually on May 15 and November 15 of each year, beginning May 15, 2016. Ameren (parent) received proceeds of $348 million , which were used to repay a portion of short-term debt. In November 2015, Ameren Corporation (parent company only) issued $350 million of 3.65% senior unsecured notes due February 15, 2026, with interest payable semiannually on February 15 and August 15 of each year, beginning February 15, 2016. Ameren (parent) received proceeds of $347 million , which were used to repay a portion of short-term debt. In May 2014, Ameren Corporation (parent company only) repaid at maturity $425 million of its 8.875% senior unsecured notes, plus accrued interest. The notes were repaid with proceeds from commercial paper issuances. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for additional information on Ameren Corporation's (parent company only) long-term debt. NOTE 4 – COMMITMENTS AND CONTINGENCIES See Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for a description of all material contingencies of Ameren Corporation (parent company only). NOTE 5 – DIVESTITURE TRANSACTIONS AND DISCONTINUED OPERATIONS On December 2, 2013, Ameren completed the divestiture of New AER to IPH in accordance with the transaction agreement between Ameren and IPH dated March 14, 2013, as amended by a letter agreement dated December 2, 2013. As a result of the divestiture in 2013, Ameren Corporation (parent company only) recorded a pretax loss on disposal of $201 million . This charge was included within "Net Loss Attributable to Ameren Common Shareholders – Discontinued Operations" in the Ameren Corporation (parent company only) Condensed Statement of Income (Loss) and Comprehensive Income (Loss) for the year ended December 31, 2013. During 2015, based on the completion of the IRS audit, Ameren Corporation (parent company only) removed a $53 million reserve for unrecognized tax benefits recorded in 2013 and recognized a tax benefit from discontinued operations. See Note 13 – Income Taxes under Part II, Item 8, of this report for additional information regarding Ameren Corporation's (parent company only) uncertain tax positions. In 2015, Ameren paid $25 million related to a previously-recorded liability pursuant to the transaction agreement between Ameren and IPH with no resulting additional impact to its results of operations. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information regarding the divestiture transactions and discontinued operations. |
Schedule II - Valuation And Qua
Schedule II - Valuation And Qualifying Accounts | 12 Months Ended |
Dec. 31, 2015 | |
Valuation and Qualifying Accounts [Abstract] | |
Valuation And Qualifying Accounts | SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS (in millions) Column A Column B Column C Column D Column E Description Balance at Beginning of Period (1) Charged to Costs and Expenses (2) Charged to Other Accounts (a) Deductions (b) Balance at End of Period Ameren: Deducted from assets – allowance for doubtful accounts: 2015 $ 21 $ 33 $ 5 $ 40 $ 19 2014 18 36 4 37 21 2013 17 35 4 38 18 Deferred tax valuation allowance: 2015 $ 10 $ 4 $ (8 ) $ — $ 6 2014 7 3 — — 10 2013 2 5 — — 7 Ameren Missouri: Deducted from assets – allowance for doubtful accounts: 2015 $ 8 $ 13 $ — $ 14 $ 7 2014 5 16 — 13 8 2013 5 16 — 16 5 Deferred tax valuation allowance: 2015 $ 1 $ — $ (1 ) $ — $ — 2014 1 — — — 1 2013 1 — — — 1 Ameren Illinois: Deducted from assets – allowance for doubtful accounts: 2015 $ 13 $ 20 $ 5 $ 26 $ 12 2014 13 20 4 24 13 2013 12 19 4 22 13 Deferred tax valuation allowance: 2015 $ 1 $ — $ (1 ) $ — $ — 2014 1 — — — 1 2013 1 — — — 1 (a) Amounts associated with the allowance for doubtful accounts relate to the uncollectible account reserve associated with receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. The amounts relating to the deferred tax valuation allowance are for items that have expired and were removed from both the underlying accumulated deferred income tax account as well as the offsetting valuation account. (b) Uncollectible accounts charged off, less recoveries. |
Summary Of Significant Accoun31
Summary Of Significant Accounting Policies (Policy) | 12 Months Ended |
Dec. 31, 2015 | |
Accounting Policies [Abstract] | |
General | Ameren, headquartered in St. Louis, Missouri, is a public utility holding company under PUHCA 2005. Ameren’s primary assets are its equity interests in its subsidiaries, including Ameren Missouri and Ameren Illinois. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. • Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas transmission and distribution business in Missouri. Ameren Missouri was incorporated in Missouri in 1922 and is successor to a number of companies, the oldest of which was organized in 1881. It is the largest electric utility in the state of Missouri. It supplies electric and natural gas service to a 24,000 -square-mile area in central and eastern Missouri. This area has an estimated population of 2.8 million and includes the Greater St. Louis area. Ameren Missouri supplies electric service to 1.2 million customers and natural gas service to 0.1 million customers. • Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric and natural gas transmission and distribution businesses in Illinois. Ameren Illinois was created by the merger of CILCO and IP with and into CIPS in 2010. CIPS was incorporated in Illinois in 1923 and was the successor to a number of companies, the oldest of which was organized in 1902. Ameren Illinois supplies electric and natural gas utility service to portions of central and southern Illinois having an estimated population of 3.1 million in an area of 40,000 square miles. Ameren Illinois supplies electric service to 1.2 million customers and natural gas service to 0.8 million customers. Ameren has various other subsidiaries that conduct activities such as the provision of shared services. Ameren also has a subsidiary, ATXI, that operates a FERC rate-regulated electric transmission business. ATXI is developing MISO-approved electric transmission projects, including the Illinois Rivers, Spoon River, and Mark Twain projects. Ameren is also pursuing projects to improve electric transmission system reliability within Ameren Missouri's and Ameren Illinois' service territories as well as competitive electric transmission investment opportunities outside of these territories, including investments outside of MISO. |
Consolidation | Ameren's financial statements are prepared on a consolidated basis, and therefore include the accounts of its majority-owned subsidiaries. Ameren Missouri and Ameren Illinois have no subsidiaries and therefore their financial statements are not prepared on a consolidated basis. All intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated. Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the reported periods. Actual results could differ from those estimates. |
Public Utilities | Regulation We are regulated by the MoPSC, the ICC, and the FERC. We defer certain costs as assets pursuant to actions of rate regulators or because of expectations that we will be able to recover such costs in future rates charged to customers. We also defer certain amounts as liabilities pursuant to actions of rate regulators or based on the expectation that such amounts will be returned to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. In addition to the cost recovery mechanisms discussed in the Purchased Gas, Power, and Fuel Rate-adjustment Mechanisms section below, Ameren Missouri and Ameren Illinois have approvals from rate regulators to use other cost recovery mechanisms. Ameren Missouri has a pension and postretirement benefit cost tracker, an uncertain tax positions tracker, a renewable energy standards cost tracker, a solar rebate program tracker, and the MEEIA energy efficiency rider. Ameren Illinois' and ATXI's electric transmission rates are determined pursuant to formula ratemaking. Additionally, Ameren Illinois' electric distribution business participates in the performance-based formula ratemaking process established pursuant to the IEIMA. Ameren Illinois also has an environmental cost rider, an asbestos-related litigation rider, an energy efficiency rider, a QIP rider, a VBA rider, and a bad debt rider. See Note 2 – Rate and Regulatory Matters for additional information on regulatory assets and liabilities. Purchased Gas, Power and Fuel Rate-adjustment Mechanisms Ameren Missouri and Ameren Illinois have various rate-adjustment mechanisms in place that provide for the recovery of purchased natural gas and electric fuel and purchased power costs without a traditional rate case proceeding. See Note 2 – Rate and Regulatory Matters for the regulatory assets and liabilities recorded at December 31, 2015 and 2014 , related to the rate-adjustment mechanisms discussed below. In Ameren Missouri’s and Ameren Illinois’ natural gas utility jurisdictions, changes in natural gas costs are reflected in billings to their natural gas utility customers through PGA clauses. The difference between actual natural gas costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to natural gas utility customers in a subsequent period. In Ameren Illinois’ retail electric utility jurisdiction, changes in purchased power and transmission service costs are reflected in billings to its electric utility customers through pass-through rate-adjustment clauses. The difference between actual purchased power and transmission service costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to electric utility customers in a subsequent period. Ameren Missouri has a FAC that allows an adjustment of electric rates three times per year for a pass-through to customers of 95% of changes in fuel and purchased power costs, including transportation charges and revenues, net of off-system sales, greater or less than the amount set in base rates, subject to MoPSC prudence review. The difference between the actual amounts incurred for these items and the amounts recovered from Ameren Missouri customers' base rates is deferred as a regulatory asset or liability. The deferred amounts are either billed or refunded to electric utility customers in a subsequent period. As of May 30, 2015, transmission revenues and substantially all transmission charges are excluded from net energy costs as a result of the April 2015 MoPSC electric rate order. Environmental Costs Liabilities for environmental costs are recorded on an undiscounted basis when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated. Costs are expensed or deferred as a regulatory asset when it is expected that the costs will be recovered from customers in future rates. |
Cash and Cash Equivalents | Cash and Cash Equivalents Cash and cash equivalents include cash on hand and temporary investments purchased with an original maturity of three months or less. |
Allowance for Doubtful Accounts Receivable | Allowance for Doubtful Accounts Receivable The allowance for doubtful accounts represents our estimate of existing accounts receivable that will ultimately be uncollectible. The allowance is calculated by applying estimated loss factors to various classes of outstanding receivables, including unbilled revenue. The loss factors used to estimate uncollectible accounts are based upon both historical collections experience and management’s estimate of future collections success given the existing and anticipated future collections environment. Ameren Illinois has a bad debt rider that adjusts rates for net write-offs of customer accounts receivable above or below those being collected in rates. |
Materials and Supplies | Materials and supplies are recorded at the lower of cost or market. Cost is determined by the average-cost method. Materials and supplies are capitalized as inventory when purchased and then expensed or capitalized as plant assets when installed, as appropriate. |
Property and Plant | Property and Plant, Net We capitalize the cost of additions to and betterments of units of property and plant. The cost includes labor, material, applicable taxes, and overhead. An allowance for funds used during construction, as discussed below, is also capitalized as a cost of our rate-regulated assets. Maintenance expenditures, including nuclear refueling and maintenance outages, are expensed as incurred. When units of depreciable property are retired, the original costs, less salvage values, are charged to accumulated depreciation. If environmental expenditures are related to assets currently in use, as in the case of the installation of pollution control equipment, the cost is capitalized and depreciated over the expected life of the asset. See Asset Retirement Obligations below and Note 3 – Property and Plant, Net, for additional information. Depreciation Depreciation is provided over the estimated lives of the various classes of depreciable property by applying composite rates on a straight-line basis to the cost basis of such property. The provision for depreciation for the Ameren Companies in 2015 , 2014 , and 2013 ranged from 3% to 4% of the average depreciable cost. |
Allowance for Funds Used During Construction | Allowance for Funds Used During Construction We capitalize allowance for funds used during construction, or the cost of borrowed funds and the cost of equity funds (preferred and common shareholders’ equity) applicable to rate-regulated construction expenditures, in accordance with the utility industry's accounting practice. Allowance for funds used during construction does not represent a current source of cash funds. This accounting practice offsets the effect on earnings of the cost of financing during construction, and it treats such financing costs in the same manner as construction charges for labor and materials. Under accepted ratemaking practice, cash recovery of allowance for funds used during construction and other construction costs occurs when completed projects are placed in service and reflected in customer rates. |
Goodwill | Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired. Ameren and Ameren Illinois' carrying amount of goodwill was $411 million at December 31, 2015 , and 2014 . All of Ameren's and Ameren Illinois' goodwill at December 31, 2015 and 2014 , was assigned to the Ameren Illinois reporting unit. We evaluate goodwill for impairment as of October 31 each year, or more frequently if events and circumstances change that would more likely than not reduce the fair value of the Ameren Illinois reporting unit below its carrying amount. Entities assessing goodwill for impairment have the option of first performing a qualitative assessment before calculating the fair value of the reporting unit. If an entity determines, on the basis of qualitative factors, that the fair value of the reporting unit is more likely than not less than the carrying amount, a two-step quantitative test is required. An entity has the option to bypass the qualitative assessment in any period and proceed directly to the first step of the quantitative test, which compares the fair value of the reporting unit to its carrying amount. If the carrying amount of the reporting unit exceeds its estimated fair value, the entity performs the second step, which requires an assignment of the reporting unit's fair value to the individual assets and liabilities in order to determine the implied fair value of the reporting unit's goodwill. If the implied fair value of goodwill is less than its carrying amount, an impairment loss is recorded. Ameren and Ameren Illinois elected to bypass the qualitative assessment and completed the first step of the quantitative test as of October 31, 2015 . Based on the results, Ameren and Ameren Illinois determined that the estimated fair value of the Ameren Illinois reporting unit significantly exceeded its carrying value as of October 31, 2015 , indicating no impairment of Ameren’s or Ameren Illinois’ goodwill. Ameren's and Ameren Illinois' valuation approach is based on a market participant view. It uses a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in estimating the fair value of the Ameren Illinois reporting unit include discount and growth rates, utility sector market performance and transactions, and projected operating results and cash flows. The goodwill assigned to the Ameren Illinois reporting unit on the December 31, 2015 balance sheets of Ameren and Ameren Illinois had no accumulated goodwill impairment losses. Ameren and Ameren Illinois will continue to monitor internal and external factors for signs of possible declines in estimated fair value and potential goodwill impairment. |
Impairment of Long-lived Assets | We evaluate long-lived assets classified as held and used for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Whether an impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets to the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, we recognize an impairment charge equal to the amount by which the carrying value exceeds the estimated fair value of the assets. In the period in which we determine an asset meets held for sale criteria, we record an impairment charge to the extent the book value exceeds its estimated fair value less cost to sell. We did not identify any events or changes in circumstances that indicated that the carrying value of long-lived assets may not be recoverable in 2015 and 2014 . |
Asset Retirement Obligations | Asset Retirement Obligations We are required to record the estimated fair value of legal obligations associated with the retirement of tangible long-lived assets in the period in which the liabilities are incurred and to capitalize a corresponding amount as part of the book value of the related long-lived asset. In subsequent periods, we are required to make adjustments to AROs based on changes in the estimated fair values of the obligations. Corresponding increases in asset book values are depreciated over the remaining useful life of the related asset. Uncertainties as to the probability, timing, or amount of cash expenditures associated with AROs affect our estimates of fair value. Ameren and Ameren Missouri have recorded AROs for retirement costs associated with Ameren Missouri’s Callaway energy center decommissioning costs, CCR facilities, and river structures. Also, Ameren, Ameren Missouri, and Ameren Illinois have recorded AROs for retirement costs associated with asbestos removal and the disposal of certain transformers. Ameren and Ameren Missouri have a nuclear decommissioning trust fund for the decommissioning of the Callaway energy center. Asset removal costs accrued by our rate-regulated operations that do not constitute legal obligations are classified as regulatory liabilities. See Note 2 – Rate and Regulatory Matters. |
Noncontrolling Interest | Noncontrolling Interests As of December 31, 2015 and 2014 , Ameren’s noncontrolling interests included the preferred stock of Ameren Missouri and Ameren Illinois. |
Revenue | Operating Revenue The Ameren Companies record operating revenue for electric or natural gas service when it is delivered to customers. We accrue an estimate of electric and natural gas revenues for service rendered but unbilled at the end of each accounting period. Ameren Illinois participates in the performance-based formula ratemaking framework pursuant to the IEIMA. In addition, Ameren Illinois' and ATXI's electric transmission delivery service operating revenues are regulated by the FERC. The provisions of the IEIMA and the FERC's electric transmission formula rate framework provide for annual reconciliations of the electric delivery and electric transmission service revenue requirements necessary to reflect the actual recoverable costs incurred in a given year with the revenue requirements in customer rates for that year, including an allowed return on equity. In each of those electric jurisdictions, if the current year's revenue requirement is greater than the revenue requirement reflected in that year's customer rates, an increase to electric operating revenues with an offset to a regulatory asset is recorded to reflect the expected recovery of those additional amounts from customers within the next two years. In each jurisdiction, if the current year's revenue requirement is less than the revenue requirement reflected in that year's customer rates, a reduction to electric operating revenues with an offset to a regulatory liability is recorded to reflect the expected refund to customers within the next two years. See Note 2 – Rate and Regulatory Matters for information regarding Ameren Illinois' revenue requirement reconciliation pursuant to the IEIMA. |
Cost Of Sales | Nuclear Fuel Ameren Missouri’s cost of nuclear fuel is capitalized and then amortized to fuel expense on a unit-of-production basis. The cost is charged to "Operating Expenses – Fuel" in the statement of income. Accounting for MISO Transactions MISO-related purchase and sale transactions are recorded by Ameren, Ameren Missouri, and Ameren Illinois using settlement information provided by MISO. Ameren Missouri records these purchase and sale transactions on a net hourly position. Ameren Missouri records net purchases in a single hour in “Operating Expenses – Purchased power” and net sales in a single hour in “Operating Revenues – Electric” in its statement of income. Ameren Illinois records net purchases in “Operating Expenses – Purchased power” in its statement of income to reflect all of its MISO transactions relating to the procurement of power for its customers. On occasion, Ameren Missouri's and Ameren Illinois' prior-period transactions will be resettled outside the routine settlement process because of a change in MISO’s tariff or a material interpretation thereof. In these cases, Ameren Missouri and Ameren Illinois recognize expenses associated with resettlements once the resettlement is probable and the resettlement amount can be estimated and recognize revenues once the resettlement amount is received. |
Stock-Based Compensation | Stock-based Compensation Stock-based compensation cost is measured at the grant date based on the fair value of the award, net of an assumed forfeiture rate. Ameren recognizes as compensation expense the estimated fair value of stock-based compensation on a straight-line basis over the requisite service period. |
Excise Taxes | Excise Taxes Ameren Missouri and Ameren Illinois collect from their customers certain excise taxes that are levied on the sale or distribution of natural gas and electricity. Excise taxes are levied on Ameren Missouri's electric and natural gas businesses and on Ameren Illinois' natural gas business. They are recorded gross in “Operating Revenues – Electric,” “Operating Revenues – Gas,” and “Operating Expenses – Taxes other than income taxes” on the statement of income or the statement of income and comprehensive income. Excise taxes for electric service in Illinois are levied on customers and are therefore not included in Ameren Illinois' revenues and expenses. |
Unamortized Debt Discount, Premium, And Expense | Unamortized Debt Discounts, Premiums, and Issuance Costs Long-term debt discounts, premiums, and issuance costs are amortized over the lives of the related issuances. Credit facility fees are amortized over the credit facility term. |
Income Taxes | Income Taxes Ameren uses an asset and liability approach for its financial accounting and reporting of income taxes, in accordance with authoritative accounting guidance. Deferred tax assets and liabilities are recognized for transactions that are treated differently for financial reporting and income tax return purposes. These deferred tax assets and liabilities are based on statutory tax rates. We recognize that regulators will probably reduce future revenues for deferred tax liabilities that were initially recorded at rates in excess of the current statutory rate. Therefore, reductions in deferred tax liabilities that were recorded because of decreases in the statutory rate have been credited to a regulatory liability. A regulatory asset has been established to recognize the probable recovery through future customer rates of tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate changes. Investment tax credits used on tax returns for prior years have been deferred as a noncurrent liability. The credits are being amortized over the useful lives of the related investment. Deferred income taxes were recorded on the temporary difference represented by the deferred investment tax credits and a corresponding regulatory liability. This recognizes the expected reduction in rates for future lower income taxes associated with the amortization of the investment tax credits. See Note 13 – Income Taxes. Ameren Missouri, Ameren Illinois, and all the other Ameren subsidiary companies are parties to a tax allocation agreement with Ameren (parent) that provides for the allocation of consolidated tax liabilities. The tax allocation agreement specifies that each party be allocated an amount of tax similar to that which would be owed or refunded had the party been separately subject to tax. Any net benefit attributable to the parent is reallocated to the other parties. This reallocation is treated as a capital contribution to the party receiving the benefit. |
Earnings Per Share | Earnings per Share Basic earnings per share is computed by dividing net income attributable to Ameren common shareholders by the weighted-average number of common shares outstanding during the period. Earnings per diluted share is computed by dividing net income attributable to Ameren common shareholders by the weighted-average number of diluted common shares outstanding during the period. Earnings per diluted share reflects the potential dilution that would occur if certain stock-based performance share units were settled. The number of performance share units assumed to be settled was 1.0 million , 1.8 million , and 1.9 million for the years ended December 31, 2015 , 2014 , and 2013 , respectively. There were no potentially dilutive securities excluded from the diluted earnings per share calculations for the years ended December 31, 2015 , 2014 , and 2013 . |
Accounting Changes and Other Matters | Accounting Changes and Other Matters The following is a summary of recently adopted authoritative accounting guidance, as well as guidance issued but not yet adopted, that could affect the Ameren Companies. Revenue from Contracts with Customers In May 2014, the FASB issued authoritative accounting guidance that changes the criteria for recognizing revenue from a contract with a customer. The underlying principle of the guidance is that an entity will recognize revenue for the transfer of promised goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The guidance also requires additional disclosures to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. Entities can apply the guidance retrospectively to each reporting period presented or retrospectively by recording a cumulative effect adjustment to retained earnings in the period of initial adoption. The Ameren Companies are currently assessing the impacts of this guidance on their results of operations, financial position, and disclosures, including their accounting for contributions in aid of construction and similar arrangements, as well as the transition method that they will use to adopt the guidance. In August 2015, the FASB deferred the effective date of this revenue guidance to the first quarter of 2018, with an option for entities to early adopt in the first quarter of 2017. The Ameren Companies do not expect to early adopt this guidance. Amendments to the Consolidation Analysis In February 2015, the FASB issued authoritative accounting guidance that amends the consolidation analysis for variable interest entities and voting interest entities. The new guidance affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. The guidance is effective for the Ameren Companies in the first quarter of 2016, and can be applied retrospectively to each reporting period presented or retrospectively by recording a cumulative effect adjustment to retained earnings in the period of initial adoption. The Ameren Companies are currently assessing this guidance and do not expect any material impacts to their results of operations, financial position or cash flows. Presentation of Debt Issuance Costs In April 2015, the FASB issued authoritative accounting guidance to simplify the presentation of debt issuance costs in the balance sheet. The guidance requires debt issuance costs to be presented as a reduction to the associated debt liability. Previously, debt issuance costs were presented in "Other assets" on the Ameren Companies' balance sheets. The Ameren Companies early adopted this standard in 2015 and applied the guidance retrospectively. At December 31, 2015, debt issuance costs of $43 million , $19 million , and $18 million were presented in "Long-term debt, net" on Ameren's, Ameren Missouri's, and Ameren Illinois' balance sheets, respectively. At December 31, 2014, debt issuance costs of $35 million , $18 million , and $17 million previously presented in "Other assets" on Ameren's, Ameren Missouri's, and Ameren Illinois' respective balance sheets were reclassified to Long-term debt, net" for comparative purposes. See Note 5 – Long-Term Debt and Equity Financings for additional information. The implementation of this authoritative accounting guidance did not affect the Ameren Companies' results of operations or cash flows. Balance Sheet Classification of Deferred Income Taxes In November 2015, the FASB issued authoritative accounting guidance to simplify the presentation of deferred income taxes in the balance sheet. The guidance requires all deferred tax assets and liabilities, along with any related valuation allowances, to be classified as noncurrent on the balance sheet. Previously, the current portion of deferred taxes was presented as "Current accumulated deferred income taxes, net" and the noncurrent portion of deferred taxes was presented as "Accumulated deferred income taxes, net" on the Ameren Companies' balance sheets. The Ameren Companies early adopted this standard in 2015 and applied the guidance retrospectively. At December 31, 2014, the current deferred income taxes of $352 million , $49 million , and $160 million , which were previously presented as "Current accumulated deferred income taxes, net" on Ameren's, Ameren Missouri's, and Ameren Illinois' respective balance sheets, were reclassified and presented in "Accumulated deferred income taxes, net" for comparative purposes. The implementation of this authoritative accounting guidance did not affect the Ameren Companies' results of operations or cash flows. Leases In February 2016, the FASB issued authoritative accounting guidance that will require an entity to recognize assets and liabilities arising from a lease. Consistent with current GAAP, the recognition, measurement, and presentation of expenses and cash flows arising from a lease will depend primarily on its classification as a finance or operating lease. The guidance also requires additional disclosures to enable users of financial statements to understand the amount, timing, and uncertainty of cash flows arising from leases. The guidance will be effective for the Ameren Companies in the first quarter of 2019, and includes an option for entities to early adopt. The guidance requires a retrospective cumulative adjustment to retained earnings in the period of initial adoption. The Ameren Companies are currently assessing the impacts of this guidance on their results of operations, financial position, cash flows and disclosures. |
Summary Of Significant Accoun32
Summary Of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Accounting Policies [Abstract] | |
Schedule Of Materials And Supplies | The following table presents a breakdown of materials and supplies for each of the Ameren Companies at December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Ameren 2015 Fuel (a) $ 173 $ — $ 173 Gas stored underground 10 87 97 Other materials and supplies 204 64 268 Total materials and supplies $ 387 $ 151 $ 538 2014 Fuel (a) $ 134 $ — $ 134 Gas stored underground 16 111 127 Other materials and supplies 197 66 263 Total materials and supplies $ 347 $ 177 $ 524 (a) Consists of coal, oil, and propane. |
Schedule Of Rates Used For Allowance For Funds Used During Construction | The following table presents the annual allowance for funds used during construction rates that were applied to construction projects in 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri 7 % 7 % 8 % Ameren Illinois 6 % 2 % 8 % |
Schedule Of Asset Retirement Obligations | The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the years ended December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Ameren Balance at December 31, 2013 $ 366 $ 3 $ 369 Liabilities incurred 2 — 2 Liabilities settled (2 ) (a) (2 ) Accretion in 2014 (b) 21 (a) 21 Change in estimates (c) 2 4 6 Balance at December 31, 2014 $ 389 $ 7 (d) $ 396 Liabilities incurred 3 — 3 Liabilities settled (1 ) (1 ) (2 ) Accretion in 2015 (b) 23 (a) 23 Change in estimates (e) 203 (a) 203 Balance at December 31, 2015 $ 617 (f) $ 6 (d) $ 623 (f) (a) Less than $1 million. (b) Accretion expense was recorded as an increase to regulatory assets at Ameren Missouri and Ameren Illinois. (c) The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren Illinois changed its fair value estimate for asbestos removal. (d) Included in “Other deferred credits and liabilities” on the balance sheet. (e) The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren and Ameren Missouri increased their AROs related to the decommissioning of the Callaway energy center by $99 million to reflect the 2015 cost study and funding analysis filed with the MoPSC, the extension of the estimated operating life until 2044, and a reduction in the discount rate assumption. See Note 10 – Callaway Energy Center for additional information. In addition, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $100 million to their AROs associated with CCR storage facilities. See Note 15 – Commitments and Contingencies for additional information. Ameren and Ameren Missouri also increased their AROs by $4 million due to a change in the estimated retirement dates of the Meramec and Rush Island energy centers as a result of the MoPSC's April 2015 electric rate order. (f) Balance included $5 million in "Other current liabilities" on the balance sheet as of December 31, 2015 |
Schedule Of Excise Taxes | The following table presents the excise taxes recorded in “Operating Revenues – Electric,” “Operating Revenues – Gas,” and “Operating Expenses – Taxes other than income taxes” for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri $ 156 $ 151 $ 152 Ameren Illinois 57 64 61 Ameren $ 213 $ 215 $ 213 |
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block] | Supplemental Cash Flow Information The following table presents additional information regarding Ameren's consolidated statement of cash flows for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Cash paid (refunded) during the year: Interest Continuing operations (a) $ 335 $ 333 $ 362 Discontinued operations (b) — — 31 $ 335 $ 333 $ 393 Income taxes, net Continuing Operations $ (17 ) $ (41 ) $ 116 Discontinued Operations 2 14 (108 ) $ (15 ) $ (27 ) $ 8 (a) Net of $17 million , $18 million , and $20 million capitalized, respectively. (b) Net of $- million, $- million, and $17 million capitalized, respectively. |
Rate And Regulatory Matters (Ta
Rate And Regulatory Matters (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Public Utilities, General Disclosures [Abstract] | |
Schedule Of Regulatory Assets And Liabilities | The following table presents our regulatory assets and regulatory liabilities at December 31, 2015 and 2014 : 2015 2014 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Current regulatory assets: Under-recovered FAC (a)(b) $ 37 $ — $ 37 $ 128 $ — $ 128 Under-recovered Illinois electric power costs (c) — 3 3 — 2 2 Under-recovered PGA (c) — 8 8 — 20 20 MTM derivative losses (d) 29 45 74 32 42 74 Energy efficiency riders (e) 23 — 23 3 — 3 IEIMA revenue requirement reconciliation adjustment (a)(f) — 103 103 — 65 65 FERC revenue requirement reconciliation adjustment (a)(g) — 8 12 — — 3 Total current regulatory assets $ 89 $ 167 $ 260 $ 163 $ 129 $ 295 Noncurrent regulatory assets: Pension and postretirement benefit costs (h) $ 95 $ 202 $ 297 $ 148 $ 275 $ 423 Income taxes (i) 254 4 258 253 3 256 Asset retirement obligations (j) — 4 4 — 5 5 Callaway costs (a)(k) 32 — 32 36 — 36 Unamortized loss on reacquired debt (a)(l) 69 69 138 72 80 152 Contaminated facilities costs (m) — 230 230 — 251 251 MTM derivative losses (d) 15 175 190 14 144 158 Storm costs (a)(n) — 9 9 — 3 3 Demand-side costs before the MEEIA implementation (a)(o) 31 — 31 44 — 44 Workers’ compensation claims (p) 6 7 13 7 7 14 Credit facilities fees (q) 4 — 4 5 — 5 Construction accounting for pollution control equipment (a)(r) 20 — 20 21 — 21 Solar rebate program (a)(s) 74 — 74 88 — 88 IEIMA revenue requirement reconciliation adjustment (a)(f) — 62 62 — 101 101 FERC revenue requirement reconciliation adjustment (a)(g) — 5 11 — 8 12 Other 5 4 9 7 6 13 Total noncurrent regulatory assets $ 605 $ 771 $ 1,382 $ 695 $ 883 $ 1,582 Current regulatory liabilities: Over-recovered FAC (b) $ 9 $ — $ 9 $ — $ — $ — Over-recovered Illinois electric power costs (c) — 6 6 — 26 26 Over-recovered PGA (c) 3 — 3 2 25 27 MTM derivative gains (d) 16 1 17 16 1 17 FERC revenue requirement reconciliation adjustment (g) — — — — 11 11 Estimated refund for FERC complaint cases, orders, and audit findings (t) — 32 45 — 21 25 Total current regulatory liabilities $ 28 $ 39 $ 80 $ 18 $ 84 $ 106 Noncurrent regulatory liabilities: Income taxes (u) $ 36 $ 6 $ 42 $ 41 $ 14 $ 55 Uncertain tax positions tracker (v) 6 — 6 7 — 7 Removal costs (w) 933 671 1,605 886 643 1,529 Asset retirement obligation (j) 167 — 167 182 — 182 Bad debt riders (x) — 6 6 — 7 7 Pension and postretirement benefit costs tracker (y) 19 — 19 24 — 24 Energy efficiency riders (e) — 36 36 — 39 39 Renewable energy credits (z) — 12 12 1 — 1 Storm tracker (aa) 9 — 9 6 — 6 Other 2 1 3 — — — Total noncurrent regulatory liabilities $ 1,172 $ 732 $ 1,905 $ 1,147 $ 703 $ 1,850 (a) These assets earn a return. (b) Under-recovered or over-recovered fuel costs to be recovered or refunded through the FAC. Specific accumulation periods aggregate the under-recovered or over-recovered costs over four months, any related adjustments that occur over the following four months, and the recovery from or refund to customers that occurs over the next eight months. (c) Under-recovered or over-recovered costs from utility customers. Amounts will be recovered from, or refunded to, customers within one year of the deferral. (d) Deferral of commodity-related derivative MTM losses or gains. See Note 7 – Derivative Financial Instruments for additional information. (e) The Ameren Missouri balance relates to the MEEIA. Beginning in January 2014, the MEEIA rider allowed Ameren Missouri to collect from or refund to customers any annual difference in the actual amounts incurred and the amounts collected from customers for the MEEIA program costs and its net shared benefits. Under the MEEIA rider, collections from or refunds to customers occur one year after the program costs and lost revenues are incurred. The Ameren Illinois balance relates to a regulatory tracking mechanism to recover its electric and natural gas costs associated with developing, implementing, and evaluating customer energy efficiency and demand response programs. Any under-recovery or over-recovery will be collected from or refunded to customers over the 12 months following the plan year. (f) The difference between Ameren Illinois' annual revenue requirement calculated under the IEIMA's performance-based formula ratemaking framework and the revenue requirement included in customer rates for that year. Subject to ICC approval, these amounts will be collected from or refunded to customers with interest within two years. (g) Ameren Illinois' and ATXI's annual revenue requirement reconciliation adjustments calculated pursuant to the FERC's electric transmission formula ratemaking framework. The under-recovery or over-recovery will be recovered from or refunded to customers within two years. (h) These costs are being amortized in proportion to the recognition of prior service costs (credits) and actuarial losses (gains) attributable to Ameren’s pension plan and postretirement benefit plans. See Note 11 – Retirement Benefits for additional information. (i) Tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate changes. This will be recovered over the expected life of the related assets. (j) Recoverable or refundable removal costs for AROs, including net realized and unrealized gains and losses related to the nuclear decommissioning trust fund investments. See Note 1 – Summary of Significant Accounting Policies – Asset Retirement Obligations and Investments. (k) Ameren Missouri’s Callaway energy center operations and maintenance expenses, property taxes, and carrying costs incurred between the plant in-service date and the date the plant was reflected in rates. These costs are being amortized over the remaining life of the energy center's original operating license through 2024. (l) Losses related to reacquired debt. These amounts are being amortized over the lives of the related new debt issuances or the original lives of the old debt issuances if no new debt was issued. (m) The recoverable portion of accrued environmental site liabilities that will be collected from electric and natural gas customers through ICC-approved cost recovery riders. The period of recovery will depend on the timing of remediation expenditures. See Note 15 – Commitments and Contingencies for additional information. (n) Storm costs from 2013 and 2015 deferred in accordance with the IEIMA. These costs are being amortized over five-year periods beginning in 2013 and 2015, respectively. (o) Demand-side costs incurred prior to implementation of the MEEIA in 2013, including the costs of developing, implementing, and evaluating customer energy efficiency and demand response programs. Costs incurred from May 2008 through September 2008 are being amortized over a 10-year period that began in March 2009. Costs incurred from October 2008 through December 2009 are being amortized until May 2017. Costs incurred from January 2010 through February 2011 are being amortized over a six-year period that began in August 2011. Costs incurred from March 2011 through July 2012 are being amortized over a six-year period that began in January 2013. Costs incurred from August 2012 through December 2012 are being amortized over a six-year period that began in June 2015. (p) The period of recovery will depend on the timing of actual expenditures. (q) Ameren Missouri’s costs incurred to enter into and maintain the Missouri Credit Agreement. Additional costs were incurred in December 2014 to amend and restate the Missouri Credit Agreement. These costs are being amortized over the life of the credit facility, ending in December 2019, to construction work in progress, which will be depreciated when assets are placed into service. (r) The MoPSC’s May 2010 electric rate order allowed Ameren Missouri to record an allowance for funds used during construction for pollution control equipment at its Sioux energy center until the cost of that equipment was included in customer rates beginning in 2011. These costs are being amortized over the expected life of the Sioux energy center, which is currently through 2033. (s) Costs associated with Ameren Missouri's solar rebate program beginning in August 2012 to fulfill its renewable energy portfolio requirement. These costs are being amortized over three years, beginning in June 2015. (t) Estimated refunds to transmission customers related to FERC orders. See Ameren Illinois Electric Transmission Rate Refund and FERC Complaint Cases above. (u) Unamortized portion of investment tax credits and reductions to deferred tax liabilities recorded at rates in excess of current statutory rates. The unamortized portion of investment tax credits and the reduction to deferred tax liabilities are being amortized over the expected life of the underlying assets. (v) The tracker is amortized over three years, beginning from the date the amounts are included in rates. See Note 13 – Income Taxes for additional information. (w) Estimated funds collected for the eventual dismantling and removal of plant from service, net of salvage value, upon retirement related to our rate-regulated operations. (x) A regulatory tracking mechanism for the difference between the level of bad debt incurred by Ameren Illinois under GAAP and the level of such costs included in electric and natural gas rates. The over-recovery relating to 2013 was refunded to customers from June 2014 through May 2015. The over-recovery relating to 2014 will be refunded to customers from June 2015 through May 2016. The over-recovery relating to 2015 will be refunded to customers from June 2016 through May 2017. (y) A regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over three to five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. (z) The Ameren Missouri balance includes the costs of renewable energy credits to fulfill Ameren Missouri's renewable energy portfolio requirement from August 2012 through December 2013, which were less than the amount included in rates. These costs are being amortized over three years beginning in June 2015. The Ameren Illinois balance includes funds collected from customers for the purchase of renewable energy credits through IPA procurements for distributed generation. The balance will be amortized as renewable energy credits are purchased. (aa) A regulatory tracking mechanism at Ameren Missouri for the difference between the level of storm costs incurred in a particular year and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. The April 2015 MoPSC order did not approve the continued use of the regulatory tracking mechanisms for storm costs. |
Property And Plant, Net (Tables
Property And Plant, Net (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Property, Plant and Equipment [Abstract] | |
Schedule Of Property And Plant, Net | The following table presents property and plant, net, for each of the Ameren Companies at December 31, 2015 and 2014 : Ameren Missouri (a) Ameren Illinois Other Ameren (a) 2015 Property and plant, at original cost: Electric $ 17,521 $ 7,253 $ 387 $ 25,161 Natural gas 445 1,997 — 2,442 17,966 9,250 387 27,603 Less: Accumulated depreciation and amortization 7,460 2,632 255 10,347 10,506 6,618 132 17,256 Construction work in progress: Nuclear fuel in process 275 — — 275 Other 402 230 636 1,268 Property and plant, net $ 11,183 $ 6,848 $ 768 $ 18,799 2014 Property and plant, at original cost: Electric $ 17,052 $ 6,517 $ 344 $ 23,913 Natural gas 431 1,854 — 2,285 17,483 8,371 344 26,198 Less: Accumulated depreciation and amortization 7,086 2,422 251 9,759 10,397 5,949 93 16,439 Construction work in progress: Nuclear fuel in process 209 — — 209 Other 261 216 299 776 Property and plant, net $ 10,867 $ 6,165 $ 392 $ 17,424 (a) Amounts in Ameren and Ameren Missouri include two CTs under separate capital lease agreements. The gross cumulative asset value of those agreements was $233 million at December 31, 2015 and 2014. The total accumulated depreciation associated with the two CTs was $72 million and $66 million at December 31, 2015 and 2014 , respectively. In addition, Ameren Missouri has investments in debt securities, which were classified as held-to-maturity and recorded in "Other assets", related to the two CTs from the city of Bowling Green and Audrain County. As of December 31, 2015 and 2014, the carrying value of these debt securities was $288 million and $294 million , respectively. |
Accrued Capital Expenditures | The following table provides accrued capital and nuclear fuel expenditures at December 31, 2015 , 2014 , and 2013 , which represent noncash investing activity excluded from the accompanying statements of cash flows: Ameren (a) Ameren Missouri Ameren Illinois Accrued capital expenditures: 2015 $ 235 $ 85 $ 92 2014 181 72 59 2013 175 74 86 Accrued nuclear fuel expenditures: 2015 16 16 (b) 2014 13 13 (b) 2013 8 8 (b) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) Not applicable. |
Short-Term Debt And Liquidity (
Short-Term Debt And Liquidity (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Short-term Debt [Line Items] | |
Schedule Of Maximum Aggregate Amount Available On Credit Agreements | The following table presents the maximum aggregate amount available to each borrower under each facility which will expire in December 2019 (the amount being each borrower's "Borrowing Sublimit"): Missouri Credit Agreement Illinois Credit Agreement Ameren $ 700 $ 500 Ameren Missouri 800 (a) Ameren Illinois (a) 800 (a) Not applicable. |
Schedule of Commercial Paper | The following table summarizes the borrowing activity and relevant interest rates under Ameren (parent)'s, Ameren Missouri's and Ameren Illinois' commercial paper programs, for the years ended December 31, 2015 and 2014 : Ameren (parent) Ameren Missouri Ameren Illinois Ameren Consolidated 2015 Average daily commercial paper outstanding $ 721 $ 42 $ 4 $ 767 Outstanding borrowings at period-end 301 — — 301 Weighted-average interest rate 0.57 % 0.50 % 0.44 % 0.55 % Peak commercial paper during period (a) $ 874 $ 294 $ 48 $ 1,108 Peak interest rate 0.91 % 0.60 % 0.60 % 0.91 % 2014 Average daily commercial paper outstanding $ 423 $ 110 $ 165 $ 639 Outstanding borrowings at period-end 585 97 32 714 Weighted-average interest rate 0.36 % 0.38 % 0.32 % 0.36 % Peak commercial paper during period (a) $ 625 $ 495 $ 300 $ 910 Peak interest rate 0.75 % 0.70 % 0.60 % 0.75 % (a) The timing of peak commercial paper issuances varies by company, and therefore the peak amounts presented by company might not equal the Ameren Consolidated peak commercial paper issuances for the period. |
Long-Term Debt And Equity Fin36
Long-Term Debt And Equity Financings (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Debt Instrument [Line Items] | |
Schedule of Long-term Debt Instruments | The following table presents long-term debt outstanding, including maturities due within one year, for the Ameren Companies as of December 31, 2015 and 2014 : 2015 2014 Ameren (Parent): 2.70% Senior unsecured notes due 2020 $ 350 $ — 3.65% Senior unsecured notes due 2026 350 — Total long-term debt, gross 700 — Less: Unamortized debt issuance costs (a) (6 ) — Long-term debt, net $ 694 $ — Ameren Missouri: Senior secured notes: (b) 4.75% Senior secured notes due 2015 — 114 5.40% Senior secured notes due 2016 260 260 6.40% Senior secured notes due 2017 425 425 6.00% Senior secured notes due 2018 (c) 179 179 5.10% Senior secured notes due 2018 199 199 6.70% Senior secured notes due 2019 (c) 329 329 5.10% Senior secured notes due 2019 244 244 5.00% Senior secured notes due 2020 85 85 3.50% Senior secured notes due 2024 350 350 5.50% Senior secured notes due 2034 184 184 5.30% Senior secured notes due 2037 300 300 8.45% Senior secured notes due 2039 (c) 350 350 3.90% Senior secured notes due 2042 (c) 485 485 3.65% Senior secured notes due 2045 250 — Environmental improvement and pollution control revenue bonds: 1992 Series due 2022 (d)(e) 47 47 1993 5.45% Series due 2028 (f) (f) (f) 1998 Series A due 2033 (d)(e) 60 60 1998 Series B due 2033 (d)(e) 50 50 1998 Series C due 2033 (d)(e) 50 50 Capital lease obligations: City of Bowling Green capital lease (Peno Creek CT) due 2022 48 54 Audrain County capital lease (Audrain County CT) due 2023 240 240 Total long-term debt, gross 4,135 4,005 Less: Unamortized discount and premium (6 ) (6 ) Less: Unamortized debt issuance costs (a) (19 ) (18 ) Less: Maturities due within one year (266 ) (120 ) Long-term debt, net $ 3,844 $ 3,861 2015 2014 Ameren Illinois: Senior secured notes: 6.20% Senior secured notes due 2016 (g) $ 54 $ 54 6.25% Senior secured notes due 2016 (h) 75 75 6.125% Senior secured notes due 2017 (h)(i) 250 250 6.25% Senior secured notes due 2018 (h)(i) 144 144 9.75% Senior secured notes due 2018 (h)(i) 313 313 2.70% Senior secured notes due 2022 (h)(i) 400 400 3.25% Senior secured notes due 2025 (h) 300 300 6.125% Senior secured notes due 2028 (h) 60 60 6.70% Senior secured notes due 2036 (h) 61 61 6.70% Senior secured notes due 2036 (g) 42 42 4.80% Senior secured notes due 2043 (h) 280 280 4.30% Senior secured notes due 2044 (h) 250 250 4.15% Senior secured notes due 2046 (h) 250 — Environmental improvement and pollution control revenue bonds: 5.90% Series 1993 due 2023 (j) (j) (j) 5.70% 1994A Series due 2024 (k) (k) (k) 1993 Series B-1 due 2028 (e)(l) 17 17 Total long-term debt, gross 2,496 2,246 Less: Unamortized discount and premium (7 ) (5 ) Less: Unamortized debt issuance costs (a) (18 ) (17 ) Less: Maturities due within one year (129 ) — Long-term debt, net $ 2,342 $ 2,224 Ameren consolidated long-term debt, net $ 6,880 $ 6,085 (a) Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies for additional information. (b) These notes are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under the Ameren Missouri mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Missouri senior secured notes currently outstanding, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2042. (c) Ameren Missouri has agreed that so long as any of the 3.90% senior secured notes due 2042 are outstanding, Ameren Missouri will not permit a release date to occur, and so long as any of the 6.70% senior secured notes due 2019, 6.00% senior secured notes due 2018 and 8.45% senior secured notes due 2039 are outstanding, Ameren Missouri will not optionally redeem, purchase, or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions. (d) These bonds are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture and have a fall-away lien provision similar to that of Ameren Missouri's senior secured notes. The bonds are also backed by an insurance guarantee policy. (e) The interest rates, and the periods during which such rates apply, vary depending on our selection of defined rate modes. Maximum interest rates could reach 18% depending on the series of bonds. The bonds are callable at 100% of par value. The average interest rates for 2015 and 2014 were as follows: 2015 2014 Ameren Missouri 1992 Series due 2022 0.06% 0.10% Ameren Missouri 1998 Series A due 2033 0.24% 0.26% Ameren Missouri 1998 Series B due 2033 0.24% 0.27% Ameren Missouri 1998 Series C due 2033 0.24% 0.26% Ameren Illinois 1993 Series B-1 due 2028 0.49% 0.21% (f) These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. (g) These notes are collaterally secured by first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. The notes have a fall-away lien provision, and Ameren Illinois could cause these notes to become unsecured at any time by redeeming the pollution control bonds 5.90% Series 1993 due 2023 (of which less than $1 million remains outstanding). (h) These notes are collaterally secured by mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois senior secured notes currently outstanding, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2024. (i) Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur, and so long as any of the 9.75% senior secured notes due 2018, 6.25% senior secured notes due 2018 and 6.125% senior secured notes due 2017 are outstanding, Ameren Illinois will not optionally redeem, purchase or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions; therefore, a release date will not occur so long as any of these notes remain outstanding. (j) These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. They are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. (k) These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. Less than $1 million principal amount of the bonds remains outstanding. (l) The bonds are callable at 100% of par value. |
Schedule Of Maturities Of Long-Term Debt | The following table presents the aggregate maturities of long-term debt, including current maturities, for the Ameren Companies at December 31, 2015 : Ameren (parent) (a) Ameren Missouri (a) Ameren Illinois (a) Ameren Consolidated 2016 $ — $ 266 $ 129 $ 395 2017 — 431 250 681 2018 — 383 457 840 2019 — 581 — 581 2020 350 92 — 442 Thereafter 350 2,382 1,660 4,392 Total $ 700 $ 4,135 $ 2,496 $ 7,331 (a) Excludes unamortized discount and premium and debt issuance costs of $6 million , $25 million , and $25 million at Ameren (parent), Ameren Missouri, and Ameren Illinois, respectively. |
Schedule Of Outstanding Preferred Stock | The following table presents the outstanding preferred stock of Ameren Missouri and Ameren Illinois, which is redeemable, at the option of the issuer, at the prices shown below as of December 31, 2015 and 2014 : Redemption Price(per share) 2015 2014 Ameren Missouri: Without par value and stated value of $100 per share, 25 million shares authorized $3.50 Series 130,000 shares $ 110.00 $ 13 $ 13 $3.70 Series 40,000 shares 104.75 4 4 $4.00 Series 150,000 shares 105.625 15 15 $4.30 Series 40,000 shares 105.00 4 4 $4.50 Series 213,595 shares 110.00 (a) 21 21 $4.56 Series 200,000 shares 102.47 20 20 $4.75 Series 20,000 shares 102.176 2 2 $5.50 Series A 14,000 shares 110.00 1 1 Total $ 80 $ 80 Ameren Illinois: With par value of $100 per share, 2 million shares authorized 4.00% Series 144,275 shares $ 101.00 $ 14 $ 14 4.08% Series 45,224 shares 103.00 5 5 4.20% Series 23,655 shares 104.00 2 2 4.25% Series 50,000 shares 102.00 5 5 4.26% Series 16,621 shares 103.00 2 2 4.42% Series 16,190 shares 103.00 2 2 4.70% Series 18,429 shares 103.00 2 2 4.90% Series 73,825 shares 102.00 7 7 4.92% Series 49,289 shares 103.50 5 5 5.16% Series 50,000 shares 102.00 5 5 6.625% Series 124,274 shares 100.00 12 12 7.75% Series 4,542 shares 100.00 1 1 Total $ 62 $ 62 Total Ameren $ 142 $ 142 (a) In the event of voluntary liquidation, $105.50 . |
Schedule of Required and Actual Debt Ratios | The following table summarizes the required and actual interest coverage ratios for interest charges, dividend coverage ratios, and bonds and preferred stock issuable as of December 31, 2015 , at an assumed interest rate of 5% and dividend rate of 6% . Required Interest Coverage Ratio (a) Actual Interest Coverage Ratio Bonds Issuable (b) Required Dividend Coverage Ratio (c) Actual Dividend Coverage Ratio Preferred Stock Issuable Ameren Missouri > 2.0 3.8 $ 3,385 > 2.5 104.0 $ 2,315 Ameren Illinois > 2.0 6.3 3,566 (d) > 1.5 2.6 203 (e) (a) Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. (b) Amount of bonds issuable based either on required coverage ratios or unfunded property additions, whichever is more restrictive. The amounts shown also include bonds issuable based on retired bond capacity of $946 million and $204 million at Ameren Missouri and Ameren Illinois, respectively. (c) Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. (d) Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. The amount of bonds issuable by Ameren Illinois is also subject to the lien restrictions contained in the Illinois Credit Agreement. (e) Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinois' articles of incorporation. |
Ameren Illinois Company | |
Debt Instrument [Line Items] | |
Debt Redemption [Table Text Block] | In January 2014, Ameren Illinois redeemed the following environmental improvement and pollution control revenue bonds at par value plus accrued interest: Senior Secured Notes Principal Amount 5.90% Series 1993 due 2023 (a) $ 32 5.70% 1994A Series due 2024 (a) 36 1993 Series C-1 5.95% due 2026 35 1993 Series C-2 5.70% due 2026 8 5.40% 1998A Series due 2028 19 5.40% 1998B Series due 2028 33 Total amount redeemed $ 163 (a) Less than $1 million principal amount of the bonds remains outstanding after redemption. |
Other Income And Expenses (Tabl
Other Income And Expenses (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Other Nonoperating Income (Expense) [Abstract] | |
Other Income And Expenses | The following table presents the components of "Other Income and Expenses" in the Ameren Companies’ statements of income (loss) for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren: (a) Miscellaneous income: Allowance for equity funds used during construction $ 30 $ 34 $ 37 Interest income on industrial development revenue bonds 27 27 27 Interest income (b) 14 10 3 Other 3 8 (c) 2 Total miscellaneous income $ 74 $ 79 $ 69 Miscellaneous expense: Donations $ 15 $ 10 $ 12 Other 15 12 14 Total miscellaneous expense $ 30 $ 22 $ 26 Ameren Missouri: Miscellaneous income: Allowance for equity funds used during construction $ 22 $ 32 $ 31 Interest income on industrial development revenue bonds 27 27 27 Interest income 1 1 — Other 2 — — Total miscellaneous income $ 52 $ 60 $ 58 Miscellaneous expense: Donations $ 5 $ 6 $ 4 Other 6 6 7 Total miscellaneous expense $ 11 $ 12 $ 11 Ameren Illinois: Miscellaneous income: Allowance for equity funds used during construction $ 8 $ 2 $ 6 Interest income (b) 12 7 2 Other 1 8 (c) 2 Total miscellaneous income $ 21 $ 17 $ 10 Miscellaneous expense: Donations $ 5 $ 4 $ 4 Other 7 4 5 Total miscellaneous expense $ 12 $ 8 $ 9 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (b) Includes Ameren Illinois' interest income on the IEIMA revenue requirement reconciliation adjustment regulatory assets. (c) Includes Ameren Illinois' income earned in 2014 from customer-requested construction. |
Derivative Financial Instrume38
Derivative Financial Instruments (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Derivative Instrument Detail [Abstract] | |
Open Gross Derivative Volumes By Commodity Type | The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of December 31, 2015 and 2014 . As of December 31, 2015 , these contracts ran through October 2018, March 2021, May 2032, and January 2019 for fuel oils, natural gas, power, and uranium, respectively. Quantity (in millions, except as indicated) 2015 2014 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) (a) 35 (b) 35 50 (b) 50 Natural gas (in mmbtu) 30 151 181 28 108 136 Power (in megawatthours) 1 10 11 1 11 12 Uranium (pounds in thousands) 494 (b) 494 332 (b) 332 (a) Fuel oils consist of heating oil and ultra-low-sulfur diesel. (b) Not applicable. |
Derivative Instruments Carrying Value | The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of December 31, 2015 and 2014 : Balance Sheet Location Ameren Missouri Ameren Illinois Ameren 2015 Natural gas Other current assets $ — $ 1 $ 1 Other assets 1 — 1 Power Other current assets 16 — 16 Total assets (a) $ 17 $ 1 $ 18 Fuel oils Other current liabilities $ 22 $ — $ 22 Other deferred credits and liabilities 7 — 7 Natural gas MTM derivative liabilities (b) 32 (b) Other current liabilities 6 — 38 Other deferred credits and liabilities 8 18 26 Power MTM derivative liabilities (b) 13 (b) Other current liabilities — — 13 Other deferred credits and liabilities — 157 157 Uranium Other current liabilities 1 — 1 Total liabilities (c) $ 44 $ 220 $ 264 2014 Fuel oils Other current assets $ 2 $ — $ 2 Natural gas Other current assets 1 1 2 Power Other current assets 15 — 15 Total assets (a) $ 18 $ 1 $ 19 Fuel oils Other current liabilities $ 22 $ — $ 22 Other deferred credits and liabilities 7 — 7 Natural gas MTM derivative liabilities (b) 31 (b) Other current liabilities 6 — 37 Other deferred credits and liabilities 6 13 19 Power MTM derivative liabilities (b) 11 (b) Other current liabilities 3 — 14 Other deferred credits and liabilities — 131 131 Uranium Other current liabilities 2 — 2 Total liabilities (c) $ 46 $ 186 $ 232 (a) Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net gains on all derivative instruments is deferred as a regulatory liability. (b) Balance sheet line item not applicable to registrant. (c) Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net losses on all derivative instruments is deferred as a regulatory asset. |
Derivative Instruments With Credit Risk-Related Contingent Features | The following table presents, as of December 31, 2015 , the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require. The additional collateral required is the net liability position allowed under the master netting arrangements or similar agreements assuming (1) the credit risk-related contingent features underlying these arrangements were triggered on December 31, 2015 , and (2) those counterparties with rights to do so requested collateral. Aggregate Fair Value of Derivative Liabilities (a) Cash Collateral Posted Potential Aggregate Amount of Additional Collateral Required (b) 2015 Ameren Missouri $ 87 $ 9 $ 72 Ameren Illinois 78 3 71 Ameren $ 165 $ 12 $ 143 (a) Before consideration of master netting arrangements or similar agreements and including NPNS and other accrual contract exposures. (b) As collateral requirements with certain counterparties are based on master netting arrangements or similar agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such arrangements. |
Offsetting Derivative Assets and Liabilities [Table Text Block] | The following table provides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of December 31, 2015 and 2014 : Gross Amounts Not Offset on the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized on the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount 2015 Assets: Ameren Missouri $ 17 $ 1 $ — $ 16 Ameren Illinois 1 — — 1 Ameren $ 18 $ 1 $ — $ 17 Liabilities: Ameren Missouri $ 44 $ 1 $ 8 $ 35 Ameren Illinois 220 — 3 217 Ameren $ 264 $ 1 $ 11 $ 252 2014 Assets: Ameren Missouri $ 18 $ 5 $ — $ 13 Ameren Illinois 1 — — 1 Ameren $ 19 $ 5 $ — $ 14 Liabilities: Ameren Missouri $ 46 $ 5 $ 5 $ 36 Ameren Illinois 186 — — 186 Ameren $ 232 $ 5 $ 5 $ 222 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Fair Value Disclosures [Abstract] | |
Fair Value Inputs, Assets and Liabilities, Quantitative Information | The following table describes the valuation techniques and unobservable inputs utilized by the Ameren Companies for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the periods ended December 31, 2015 and 2014 : Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Level 3 Derivative asset and liability – commodity contracts (a) : 2015 Natural Gas $ 1 $ (1 ) Option model Volatilities(%) (b) 35 – 55 45 Nodal basis($/mmbtu) (c) (0.30) – 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (b) (0.10) – 0 (0.10) Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Counterparty credit risk(%) (c)(d) 0.40 – 12 7 Ameren Missouri credit risk(%) (c)(d) 0.40 (e) Power (f) 16 (170 ) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps($/MWh) (g) 22 – 39 29 Estimated auction price for FTRs($/MW) (b) (270) – 2,057 211 Nodal basis($/MWh) (g) (10) – (1) (3) Counterparty credit risk(%) (c)(d) 0.86 (e) Ameren Illinois credit risk(%) (c)(d) 0.40 (e) Fundamental energy production model Estimated future gas prices($/mmbtu) (b) 3 – 4 4 Escalation rate(%) (b)(h) 3 (e) Contract price allocation Estimated renewable energy credit costs($/credit) (b) 5 – 7 6 Uranium — (1 ) Option model Volatilities(%) (b) 20 (e) Discounted cash flow Average forward uranium pricing($/pound) (b) 35 – 42 37 Ameren Missouri credit risk(%) (c)(d) 0.40 (e) 2014 Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (c) 3 – 39 32 Discounted cash flow Ameren Missouri credit risk(%) (c)(d) 0.43 (e) Escalation rate(%) (b)(i) 5 (e) Natural Gas 1 (2 ) Option model Volatilities(%) (c) 31 – 144 63 Nodal basis($/mmbtu) (b) (0.40) – 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (b) (0.40) – 0.10 (0.20) Counterparty credit risk(%) (c)(d) 0.43 – 13 3 Ameren Missouri and Ameren Illinois credit risk(%) (c)(d) 0.43 (e) Power (f) 11 (144 ) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps($/MWh) (g) 27 – 50 32 Estimated auction price for FTRs($/MW) (b) (1,833) – 2,743 171 Nodal basis($/MWh) (b) (6) – 0 (2) Counterparty credit risk(%) (c)(d) 0.26 (e) Ameren Missouri and Ameren Illinois credit risk(%) (c)(d) 0.43 (e) Fundamental energy production model Estimated future gas prices($/mmbtu) (b) 4 – 5 4 Escalation rate(%) (b)(h) 0 – 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (b) 5 – 7 6 Uranium — (2 ) Discounted cash flow Average forward uranium pricing($/pound) (b) 35 – 40 36 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (c) Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. (d) Counterparty credit risk is applied only to counterparties with derivative asset balances. Ameren Missouri and Ameren Illinois credit risk is applied only to counterparties with derivative liability balances. (e) Not applicable. (f) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2019. Valuations beyond 2019 use fundamentally modeled pricing by month for peak and off-peak demand. (g) The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes because of their opposing positions. (h) Escalation rate applies to power prices 2026 and beyond. (i) Escalation rate applies to fuel oil prices 2017 and beyond. |
Schedule Of Fair Value Hierarchy Of Assets And Liabilities Measured At Fair Value On Recurring Basis | The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of December 31, 2015 : Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Assets: Ameren Derivative assets – commodity contracts (a) : Natural gas $ — $ 1 $ 1 $ 2 Power — — 16 16 Total derivative assets – commodity contracts $ — $ 1 $ 17 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 4 $ — $ — $ 4 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 109 — 109 Corporate bonds — 58 — 58 Other — 22 — 22 Total nuclear decommissioning trust fund $ 368 $ 189 $ — $ 557 (b) Total Ameren $ 368 $ 190 $ 17 $ 575 Ameren Missouri Derivative assets – commodity contracts (a) : Natural gas $ — $ — $ 1 $ 1 Power — — 16 16 Total derivative assets – commodity contracts $ — $ — $ 17 $ 17 Nuclear decommissioning trust fund: Cash and cash equivalents $ 4 $ — $ — $ 4 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 109 — 109 Corporate bonds — 58 — 58 Other — 22 — 22 Total nuclear decommissioning trust fund $ 368 $ 189 $ — $ 557 (b) Total Ameren Missouri $ 368 $ 189 $ 17 $ 574 Ameren Illinois Derivative assets – commodity contracts (a) : Natural gas $ — $ 1 $ — $ 1 Liabilities: Ameren Derivative liabilities – commodity contracts (a) : Fuel oils $ 29 $ — $ — $ 29 Natural gas 1 62 1 64 Power — — 170 170 Uranium — — 1 1 Total Ameren $ 30 $ 62 $ 172 $ 264 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Ameren Missouri Derivative liabilities – commodity contracts (a) : Fuel oils $ 29 $ — $ — $ 29 Natural gas — 13 1 14 Power — — — — Uranium — — 1 1 Total Ameren Missouri $ 29 $ 13 $ 2 $ 44 Ameren Illinois Derivative liabilities – commodity contracts (a) : Natural gas $ 1 $ 49 $ — $ 50 Power — — 170 170 Total Ameren Illinois $ 1 $ 49 $ 170 $ 220 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Balance excludes $(1) million of receivables, payables, and accrued income, net. The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 : Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Assets: Ameren Derivative assets – commodity contracts (a) : Fuel oils $ — $ — $ 2 $ 2 Natural gas — 1 1 2 Power — 4 11 15 Total derivative assets – commodity contracts $ — $ 5 $ 14 $ 19 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ — $ — $ 1 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 102 — 102 Corporate bonds — 63 — 63 Other — 17 — 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ — $ 547 (b) Total Ameren $ 365 $ 187 $ 14 $ 566 Ameren Missouri Derivative assets – commodity contracts (a) : Fuel oils $ — $ — $ 2 $ 2 Natural gas — 1 — 1 Power — 4 11 15 Total derivative assets – commodity contracts $ — $ 5 $ 13 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ — $ — $ 1 Equity securities: U.S. large capitalization 364 — — 364 Debt securities: U.S. Treasury and agency securities — 102 — 102 Corporate bonds — 63 — 63 Other — 17 — 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ — $ 547 (b) Total Ameren Missouri $ 365 $ 187 $ 13 $ 565 Ameren Illinois Derivative assets – commodity contracts (a) : Natural gas $ — $ — $ 1 $ 1 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Liabilities: Ameren Derivative liabilities – commodity contracts (a) : Fuel oils $ 21 $ — $ 8 $ 29 Natural gas 1 53 2 56 Power — 1 144 145 Uranium — — 2 2 Total Ameren $ 22 $ 54 $ 156 $ 232 Ameren Missouri Derivative liabilities – commodity contracts (a) : Fuel oils $ 21 $ — $ 8 $ 29 Natural gas 1 10 1 12 Power — 1 2 3 Uranium — — 2 2 Total Ameren Missouri $ 22 $ 11 $ 13 $ 46 Ameren Illinois Derivative liabilities – commodity contracts (a) : Natural gas $ — $ 43 $ 1 $ 44 Power — — 142 142 Total Ameren Illinois $ — $ 43 $ 143 $ 186 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Balance excludes $2 million of receivables, payables, and accrued income, net. |
Schedule Of Changes In The Fair Value Of Financial Assets And Liabilities Classified As Level 3 In The Fair Value Hierarchy | The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the year ended December 31, 2015 : Net Derivative Commodity Contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2015 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 5 (a) 5 Transfers out of Level 3 2 (a) 2 Ending balance at December 31, 2015 $ — $ (a) $ — Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (a) $ — Natural gas: Beginning balance at January 1, 2015 $ (1 ) $ — $ (1 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: — 1 1 Settlements 1 (1 ) — Ending balance at December 31, 2015 $ — $ — $ — Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ — $ — Power: Beginning balance at January 1, 2015 $ 9 $ (142 ) $ (133 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: 2 (41 ) (39 ) Purchases 29 — 29 Settlements (23 ) 13 (10 ) Transfers out of Level 3 (1 ) — (1 ) Ending balance at December 31, 2015 $ 16 $ (170 ) $ (154 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (39 ) $ (39 ) Uranium: Beginning balance at January 1, 2015 $ (2 ) $ (a) $ (2 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 2 (a) 2 Ending balance at December 31, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2015 $ — $ (a) $ — (a) Not applicable. The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the year ended December 31, 2014 : Net Derivative Commodity Contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2014 $ 5 $ (a) $ 5 Realized and unrealized gains (losses) included in regulatory assets/liabilities: (9 ) (a) (9 ) Settlements (2 ) (a) (2 ) Ending balance at December 31, 2014 $ (6 ) $ (a) $ (6 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ (6 ) $ (a) $ (6 ) Natural gas: Beginning balance at January 1, 2014 $ — $ — $ — Realized and unrealized gains (losses) included in regulatory assets/liabilities: — 1 1 Purchases — (2 ) (2 ) Sales (1 ) — (1 ) Settlements — 1 1 Ending balance at December 31, 2014 $ (1 ) $ — $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ — $ 2 $ 2 Power: Beginning balance at January 1, 2014 $ 19 $ (108 ) $ (89 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (14 ) (39 ) (53 ) Purchases 34 — 34 Sales (1 ) — (1 ) Settlements (29 ) 5 (24 ) Ending balance at December 31, 2014 $ 9 $ (142 ) $ (133 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ — $ (43 ) $ (43 ) Uranium: Beginning balance at January 1, 2014 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities: (1 ) (a) (1 ) Settlements 5 (a) 5 Ending balance at December 31, 2014 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2014 $ (1 ) $ (a) $ (1 ) (a) Not applicable. |
Schedule Of Carrying Amounts And Estimated Fair Values Of Long-Term Debt And Preferred Stock | following table presents the carrying amounts and estimated fair values of our long-term debt, capital lease obligations and preferred stock at December 31, 2015 and 2014 : 2015 2014 Carrying Amount Fair Value Carrying Amount Fair Value Ameren: (a) Long-term debt and capital lease obligations (including current portion) (b) $ 7,275 $ 7,814 $ 6,205 $ 7,135 Preferred stock 142 125 142 122 Ameren Missouri: Long-term debt and capital lease obligations (including current portion) (b) $ 4,110 $ 4,449 $ 3,981 $ 4,518 Preferred stock 80 75 80 73 Ameren Illinois: Long-term debt (including current portion) (b) $ 2,471 $ 2,665 $ 2,224 $ 2,517 Preferred stock 62 50 62 49 (a) Preferred stock is recorded in "Noncontrolling Interests" on the consolidated balance sheet. |
Nuclear Decommissioning Trust40
Nuclear Decommissioning Trust Fund Investments (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |
Fair Value Of Securities In Nuclear Decommissioning Trust Fund | The following table presents the costs and fair values of investments in debt and equity securities in Ameren's and Ameren Missouri’s nuclear decommissioning trust fund at December 31, 2015 and 2014 : Security Type Cost Gross Unrealized Gain Gross Unrealized Loss Fair Value 2015 Debt securities $ 191 $ 2 $ 4 $ 189 Equity securities 147 224 7 364 Cash 4 — — 4 Other (a) (1 ) — — (1 ) Total $ 341 $ 226 $ 11 $ 556 2014 Debt securities $ 175 $ 7 $ — $ 182 Equity securities 138 230 4 364 Cash 1 — — 1 Other (a) 2 — — 2 Total $ 316 $ 237 $ 4 $ 549 (a) Represents payables relating to pending security purchases, net of receivables related to pending security sales and interest. |
Schedule Of Unrealized Losses On Available-For-Sale Investments Included In Nuclear Decommissioning Trust Fund | The following table presents the fair value and the gross unrealized losses of the available-for-sale securities held in Ameren's and Ameren Missouri's nuclear decommissioning trust fund. They are aggregated by investment category and the length of time that individual securities have been in a continuous unrealized loss position at December 31, 2015 : Less than 12 Months 12 Months or Greater Total Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Debt securities $ 136 $ 3 $ 4 $ 1 $ 140 $ 4 Equity securities 16 3 4 4 20 7 Total $ 152 $ 6 $ 8 $ 5 $ 160 $ 11 |
Regulatory Asset | |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |
Proceeds From Sale Of Investments In Nuclear Decommissioning Trust Fund And Gross Realized Gains And Losses | The following table presents proceeds from the sale and maturities of investments in Ameren Missouri’s nuclear decommissioning trust fund and the gross realized gains and losses resulting from those sales for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Proceeds from sales and maturities $ 349 $ 391 $ 196 Gross realized gains 8 7 7 Gross realized losses 2 2 5 |
Fair Value Of Securities In Nuclear Decommissioning Trust Fund According To Their Contractual Maturities | The following table presents the costs and fair values of investments in debt securities in Ameren's and Ameren Missouri’s nuclear decommissioning trust fund according to their contractual maturities at December 31, 2015 : Cost Fair Value Less than 5 years $ 106 $ 105 5 years to 10 years 42 41 Due after 10 years 43 43 Total $ 191 $ 189 |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Summary Of Benefit Liability Recorded | The following table presents the net benefit liability recorded on the balance sheets of each of the Ameren Companies as of December 31, 2015 and 2014 : 2015 2014 Ameren (a) $ 567 $ 710 Ameren Missouri 236 277 Ameren Illinois 219 278 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Funded Status Of Benefit Plans And Amounts Included In Regulatory Assets And OCI | The following table presents the funded status of Ameren's pension and postretirement benefit plans as of December 31, 2015 and 2014 . It also provides the amounts included in regulatory assets and accumulated OCI at December 31, 2015 and 2014 , that have not been recognized in net periodic benefit costs. 2015 2014 Pension Benefits (a) Postretirement Benefits (a) Pension Benefits (a) Postretirement Benefits (a) Accumulated benefit obligation at end of year $ 3,995 $ (b) $ 4,176 $ (b) Change in benefit obligation: Net benefit obligation at beginning of year $ 4,410 $ 1,203 $ 3,900 $ 1,096 Service cost 92 24 79 19 Interest cost 174 48 183 50 Participant contributions — 8 — 16 Actuarial (gain) loss (256 ) (133 ) 462 84 Settlement (2 ) — — — Benefits paid (221 ) (56 ) (214 ) (65 ) Federal subsidy on benefits paid (b) — (b) 3 Net benefit obligation at end of year 4,197 1,094 4,410 1,203 Change in plan assets: Fair value of plan assets at beginning of year 3,794 1,109 3,461 1,074 Actual return on plan assets (29 ) (8 ) 448 75 Employer contributions 111 18 99 6 Federal subsidy on benefits paid (b) — (b) 3 Participant contributions — 8 — 16 Settlements (2 ) — — — Benefits paid (221 ) (56 ) (214 ) (65 ) Fair value of plan assets at end of year 3,653 1,071 3,794 1,109 Funded status – deficiency 544 23 616 94 Accrued benefit cost at December 31 $ 544 $ 23 $ 616 $ 94 Amounts recognized in the balance sheet consist of: Noncurrent asset (c) $ — $ (18 ) $ — $ — Current liability (d) 3 2 3 2 Noncurrent liability 541 39 613 92 Net liability recognized $ 544 $ 23 $ 616 $ 94 Amounts recognized in regulatory assets consist of: Net actuarial (gain) loss $ 395 $ (82 ) $ 452 $ (7 ) Prior service cost (credit) (5 ) (11 ) (6 ) (16 ) Amounts (pretax) recognized in accumulated OCI consist of: Net actuarial (gain) loss 17 (3 ) 29 (5 ) Prior service cost (credit) — — — (1 ) Total $ 407 $ (96 ) $ 475 $ (29 ) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) Not applicable. (c) Included in "Other assets" on Ameren's consolidated balance sheet. (d) Included in "Other current liabilities" on Ameren's consolidated balance sheet. |
Assumptions Used To Determine Benefit Obligations | The following table presents the assumptions used to determine our benefit obligations at December 31, 2015 and 2014 : Pension Benefits Postretirement Benefits 2015 2014 2015 2014 Discount rate at measurement date 4.50 % 4.00 % 4.50 % 4.00 % Increase in future compensation 3.50 3.50 3.50 3.50 Medical cost trend rate (initial) (a) (a) 5.00 5.00 Medical cost trend rate (ultimate) (a) (a) 5.00 5.00 Years to ultimate rate (a) (a) — — (a) Not applicable |
Schedule Of Cash Contributions Made To Benefit Plans | The following table presents the cash contributions made to our defined benefit retirement plan and to our postretirement plans during 2015 , 2014 , and 2013 : Pension Benefits Postretirement Benefits 2015 2014 2013 2015 2014 2013 Ameren Missouri $ 47 $ 41 $ 60 $ 8 $ 3 $ 10 Ameren Illinois 45 39 50 8 2 11 Other 19 19 46 2 1 4 Ameren (a) 111 99 156 18 6 25 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Target Allocation Of The Plans' Asset Categories | The following table presents our target allocations for 2016 and our pension and postretirement plans’ asset categories as of December 31, 2015 and 2014 : Asset Category Target Allocation 2016 Percentage of Plan Assets at December 31, 2015 2014 Pension Plan: Cash and cash equivalents 0% – 5% 1 % 2 % Equity securities: U.S. large-capitalization 29% – 39% 34 % 34 % U.S. small- and mid-capitalization 3% – 13% 7 % 7 % International and emerging markets 9% – 19% 13 % 12 % Total equity 51% – 61% 54 % 53 % Debt securities 35% – 45% 40 % 41 % Real estate 0% – 9% 5 % 4 % Private equity 0% – 5% (a) (a) Total 100 % 100 % Postretirement Plans: Cash and cash equivalents 0% – 7% 4 % 4 % Equity securities: U.S. large-capitalization 34% – 44% 39 % 40 % U.S. small- and mid-capitalization 2% – 12% 7 % 7 % International 9% – 19% 13 % 13 % Total equity 55% – 65% 59 % 60 % Debt securities 33% – 43% 37 % 36 % Total 100 % 100 % (a) Less than 1% of plan assets. |
Changes In The Fair Value Of Plan Assets Classified As Level 3 | The following table summarizes the changes in the fair value of the pension plan assets classified as Level 3 in the fair value hierarchy for each of the years ended December 31, 2015 and 2014 : Beginning Balance at January 1, Actual Return on Plan Assets Related to Assets Still Held at the Reporting Date Actual Return on Plan Assets Related to Assets Sold During the Period Purchases, Sales, and Settlements, Net Net Transfers into (out of) of Level 3 Ending Balance at December 31, 2015: Real estate $ 147 $ 14 $ — $ 7 $ — $ 168 Private equity 13 (9 ) 9 (5 ) — 8 2014: Real estate $ 131 $ 11 $ — $ 5 $ — $ 147 Private equity 15 (9 ) 10 (3 ) — 13 |
Components Of Net Periodic Benefit Cost | The following table presents the components of the net periodic benefit cost of Ameren's pension and postretirement benefit plans during 2015 , 2014 , and 2013 : Pension Benefits (a) Postretirement Benefits (a) 2015 Service cost $ 92 $ 24 Interest cost 174 48 Expected return on plan assets (248 ) (68 ) Amortization of: Prior service credit (1 ) (5 ) Actuarial loss 74 5 Settlement Loss 1 — Net periodic benefit cost $ 92 $ 4 2014 Service cost $ 79 $ 19 Interest cost 183 50 Expected return on plan assets (229 ) (65 ) Amortization of: Prior service credit (1 ) (5 ) Actuarial (gain) loss 49 (7 ) Net periodic benefit cost (benefit) $ 81 $ (8 ) 2013 Service cost $ 91 $ 22 Interest cost 163 46 Expected return on plan assets (218 ) (62 ) Amortization of: Prior service credit (2 ) (6 ) Actuarial loss 87 8 Curtailment gain (12 ) (7 ) Net periodic benefit cost (b) $ 109 $ 1 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) The net periodic benefit cost includes a $6 million and a $7 million net gain for pension benefits and postretirement benefits, respectively, which was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). This net gain includes the curtailment gain recognized in 2013 as a result of a significant reduction in employees as of the December 2, 2013 closing date of the New AER divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. |
Summary Of Estimated Amortizable Amounts From Regulatory Assets and Accumulated OCI Into Net Periodic Benefit Cost | The estimated amounts that will be amortized from regulatory assets and accumulated OCI into Ameren's net periodic benefit cost in 2016 are as follows: Pension Benefits (a) Postretirement Benefits (a) Regulatory assets: Prior service credit $ (1 ) $ (4 ) Net actuarial loss 46 (3 ) Accumulated OCI: Net actuarial (gain) loss (3 ) (2 ) Total $ 42 $ (9 ) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Summary Of Benefit Plan Costs Incurred | The Ameren Companies are responsible for their share of the pension and postretirement benefit costs. The following table presents the pension costs and the postretirement benefit costs incurred and included in continuing operations for the years ended December 31, 2015 , 2014 , and 2013 : Pension Costs Postretirement Costs 2015 2014 2013 2015 2014 2013 Ameren Missouri (a) $ 54 $ 50 $ 69 $ 8 $ 3 $ 8 Ameren Illinois 38 30 41 (3 ) (9 ) — Other — 1 5 (1 ) (2 ) — Ameren (b) 92 81 115 4 (8 ) 8 (a) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. (b) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Schedule Of Expected Payments From Qualified Trust And Company Funds | The expected pension and postretirement benefit payments from qualified trust and company funds, which reflect expected future service, as of December 31, 2015 , are as follows: Pension Benefits Postretirement Benefits Paid from Qualified Trust Funds Paid from Company Funds Paid from Qualified Trust Funds Paid from Company Funds 2016 $ 233 $ 3 $ 55 $ 2 2017 244 3 58 2 2018 250 3 60 2 2019 257 3 62 2 2020 261 3 65 2 2021 – 2025 1,377 13 341 12 |
Assumptions Used To Determine Net Periodic Benefit Cost | The following table presents the assumptions used to determine net periodic benefit cost for our pension and postretirement benefit plans for the years ended December 31, 2015 , 2014 , and 2013 : Pension Benefits Postretirement Benefits 2015 2014 2013 2015 2014 2013 Discount rate at measurement date 4.00 % 4.75 % 4.00 % 4.00 % 4.75 % 4.00 % Expected return on plan assets 7.25 7.25 7.50 7.00 7.00 7.25 Increase in future compensation 3.50 3.50 3.50 3.50 3.50 3.50 Medical cost trend rate (initial) (a) (a) (a) 5.00 5.00 5.00 Medical cost trend rate (ultimate) (a) (a) (a) 5.00 5.00 5.00 Years to ultimate rate (a) (a) (a) — — — (a) Not applicable |
Schedule Of Potential Changes In Key Assumptions | The table below reflects the sensitivity of Ameren’s plans to potential changes in key assumptions: Pension Benefits Postretirement Benefits Service Cost and Interest Cost Projected Benefit Obligation Service Cost and Interest Cost Postretirement Benefit Obligation 0.25% decrease in discount rate $ (1 ) $ 130 $ 1 $ 37 0.25% increase in salary scale 2 14 — — 1.00% increase in annual medical trend — — 3 44 1.00% decrease in annual medical trend — — (3 ) (44 ) |
Schedule Of Matching Contributions | The following table presents the portion of the matching contribution to the Ameren 401(k) plan attributable to the continuing operations for each of the Ameren Companies for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren Missouri $ 16 $ 16 $ 16 Ameren Illinois 12 11 10 Other 1 1 1 Ameren (a) 29 28 27 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Pension Benefits | |
Target Allocation Of The Plans' Asset Categories | The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2015 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ — $ 20 $ — $ 20 Equity securities: U.S. large-capitalization — 1,296 — 1,296 U.S. small- and mid-capitalization 268 — — 268 International and emerging markets 122 369 — 491 Debt securities: Corporate bonds — 631 — 631 Municipal bonds — 104 — 104 U.S. Treasury and agency securities 6 751 — 757 Other — 5 — 5 Real estate — — 168 168 Private equity — — 8 8 Total $ 396 $ 3,176 $ 176 $ 3,748 Less: Medical benefit assets at December 31 (a) (123 ) Plus: Net receivables at December 31 (b) 28 Fair value of pension plans assets at year end $ 3,653 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2014 : Quoted Prices in Active Markets for Identified Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ — $ 38 $ — $ 38 Equity securities: U.S. large-capitalization — 1,331 — 1,331 U.S. small- and mid-capitalization 270 — — 270 International and emerging markets 134 360 — 494 Debt securities: Corporate bonds — 1,026 — 1,026 Municipal bonds — 175 — 175 U.S. Treasury and agency securities 6 366 — 372 Other — 31 — 31 Real estate — — 147 147 Private equity — — 13 13 Derivative assets 1 — — 1 Total $ 411 $ 3,327 $ 160 $ 3,898 Less: Medical benefit assets at December 31 (a) (125 ) Plus: Net receivables at December 31 (b) 21 Fair value of pension plans assets at year end $ 3,794 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. |
Postretirement Benefits | |
Target Allocation Of The Plans' Asset Categories | The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the postretirement benefit plans assets measured at fair value as of December 31, 2015 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ 61 $ — $ — $ 61 Equity securities: U.S. large-capitalization 272 98 — 370 U.S. small- and mid-capitalization 65 — — 65 International 33 93 — 126 Other — 7 — 7 Debt securities: Corporate bonds — 138 — 138 Municipal bonds — 114 — 114 U.S. Treasury and agency securities — 55 — 55 Other — 40 — 40 Total $ 431 $ 545 $ — $ 976 Plus: Medical benefit assets at December 31 (a) 123 Less: Net payables at December 31 (b) (28 ) Fair value of postretirement benefit plans assets at year end $ 1,071 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by interest receivables and receivables related to pending security sales. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the postretirement benefit plans assets measured at fair value as of December 31, 2014 : Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Cash and cash equivalents $ 89 $ — $ — $ 89 Equity securities: U.S. large-capitalization 291 101 — 392 U.S. small- and mid-capitalization 70 — — 70 International 37 94 — 131 Other — 7 — 7 Debt securities: Corporate bonds — 105 — 105 Municipal bonds — 111 — 111 U.S. Treasury and agency securities — 89 — 89 Other — 44 — 44 Total $ 487 $ 551 $ — $ 1,038 Plus: Medical benefit assets at December 31 (a) 125 Less: Net payables at December 31 (b) (54 ) Fair value of postretirement benefit plans assets at year end $ 1,109 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by Medicare, interest receivables, and receivables related to pending security sales. |
Stock-Based Compensation (Table
Stock-Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Summary Of Nonvested Shares Related To Long-Term Incentive Plan | A summary of nonvested shares at December 31, 2015 , and changes during the year ended December 31, 2015 , under the 2006 Incentive Plan and the 2014 Incentive Plan are presented below: Performance Share Units Share Units Weighted-average Fair Value per Share Unit Nonvested at January 1, 2015 1,162,377 $ 35.35 Granted (a) 570,313 52.88 Forfeitures (1,944 ) 34.75 Earned and vested (b) (705,876 ) 33.93 Nonvested at December 31, 2015 1,024,870 $ 46.08 (a) Includes performance share units (share units) granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. (b) Includes share units granted in 2013 that vested as of December 31, 2015 , that were earned pursuant to the terms of the award grants. Also includes share units that vested due to attainment of retirement eligibility by certain employees. Actual shares issued for retirement-eligible employees will vary depending on actual performance over the three-year measurement period. |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Income Tax Disclosure [Abstract] | |
Schedule Of Effective Income Tax Rate Reconciliation | The following table presents the principal reasons for the difference between the effective income tax rate and the statutory federal income tax rate for the years ended December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Ameren 2015 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Depreciation differences — (2 ) (1 ) Amortization of investment tax credit (1 ) — (1 ) State tax 3 5 5 Other permanent items — (1 ) — Effective income tax rate 37 % 37 % 38 % 2014 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Amortization of investment tax credit (1 ) — (1 ) State tax 3 6 4 Other permanent items — — 1 Effective income tax rate 37 % 41 % 39 % 2013 Statutory federal income tax rate: 35 % 35 % 35 % Increases (decreases) from: Depreciation differences — (1 ) — Amortization of investment tax credit (1 ) — (1 ) State tax 3 6 4 Other permanent items 1 — — Effective income tax rate 38 % 40 % 38 % |
Schedule Of Components Of Income Tax Expense (Benefit) | The following table presents the components of income tax expense (benefit) for the years ended December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Other Ameren 2015 Current taxes: Federal $ 110 $ (83 ) $ (29 ) $ (2 ) State 17 (11 ) (10 ) (4 ) Deferred taxes: Federal 71 193 35 299 State 16 29 31 76 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense $ 209 $ 127 $ 27 $ 363 2014 Current taxes: Federal $ (13 ) $ (51 ) $ 27 $ (37 ) State (3 ) (2 ) (32 ) (37 ) Deferred taxes: Federal 222 159 (12 ) 369 State 28 38 22 88 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense $ 229 $ 143 $ 5 $ 377 2013 Current taxes: Federal $ 136 $ (15 ) $ (239 ) (a) $ (118 ) State 41 21 (43 ) (a) 19 Deferred taxes: Federal 64 99 205 (a) 368 State 6 6 36 (a) 48 Deferred investment tax credits, amortization (5 ) (1 ) — (6 ) Total income tax expense (benefit) $ 242 $ 110 $ (41 ) $ 311 (a) These amounts are substantially related to the reversal of unrecognized tax benefits as a result of IRS guidance related to the deductibility of expenditures to maintain, replace, or improve steam or electric power generation property, along with casualty loss deductions for storm damage. The amounts also reflect the increase in deferred tax expense due to available net operating losses. |
Schedule Of Deferred Tax Assets And Liabilities Resulting From Temporary Differences | The following table presents the deferred tax assets and deferred tax liabilities recorded as a result of temporary differences at December 31, 2015 and 2014 : Ameren Missouri Ameren Illinois Other Ameren 2015 Accumulated deferred income taxes, net liability (asset): Plant related $ 2,931 $ 1,587 $ 37 $ 4,555 Regulatory assets, net 81 (1 ) — 80 Deferred employee benefit costs (76 ) (40 ) (91 ) (207 ) Revenue requirement reconciliation adjustments — 66 — 66 Tax carryforwards (65 ) (133 ) (405 ) (603 ) Other (27 ) 1 20 (6 ) Total net accumulated deferred income tax liabilities (assets) (a) $ 2,844 $ 1,480 $ (439 ) $ 3,885 2014 Accumulated deferred income taxes, net liability (asset): Plant related $ 2,776 $ 1,393 $ 16 $ 4,185 Regulatory assets, net 82 (5 ) 1 78 Deferred employee benefit costs (80 ) (45 ) (95 ) (220 ) Revenue requirement reconciliation adjustments — 66 3 69 Tax carryforwards (107 ) (139 ) (429 ) (675 ) Other 86 (22 ) 70 134 Total net accumulated deferred income tax liabilities (assets) (a) $ 2,757 $ 1,248 $ (434 ) $ 3,571 (a) Reflects the adoption of the new authoritative accounting guidance for the balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. |
Schedule Of Net Operating Loss Carryforwards And Tax Credit Carryforwards | The following table presents the components of deferred tax assets relating to net operating loss carryforwards, tax credit carryforwards, and charitable contribution carryforwards at December 31, 2014 : Ameren Missouri Ameren Illinois Other Ameren Net operating loss carryforwards: Federal (a) $ 75 $ 127 $ 255 $ 457 State (b) 11 10 53 74 Total net operating loss carryforwards $ 86 $ 137 $ 308 $ 531 Tax credit carryforwards: Federal (c) $ 21 $ 1 $ 77 $ 99 State (d) 1 2 33 36 State valuation allowance (e) (1 ) (1 ) (2 ) (4 ) Total tax credit carryforwards $ 21 $ 2 $ 108 $ 131 Charitable contribution carryforwards (f) $ — $ — $ 19 $ 19 Valuation allowance (e) — — (6 ) (6 ) Total charitable contribution carryforwards $ — $ — $ 13 $ 13 (a) Will begin to expire in 2028 (b) Will begin to expire in 2019 . (c) Will begin to expire in 2029 . (d) Began to expire in 2013 . (e) See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. (f) Began to expire in 2013 . The following table presents the components of deferred tax assets relating to net operating loss carryforwards, tax credit carryforwards, and charitable contribution carryforwards at December 31, 2015 : Ameren Missouri Ameren Illinois Other Ameren Net operating loss carryforwards: Federal (a) $ 35 $ 127 $ 245 $ 407 State (b) 4 4 38 46 Total net operating loss carryforwards $ 39 $ 131 $ 283 $ 453 Tax credit carryforwards: Federal (c) $ 26 $ 1 $ 78 $ 105 State (d) — 1 40 41 State valuation allowance (e) — — (2 ) (2 ) Total tax credit carryforwards $ 26 $ 2 $ 116 $ 144 Charitable contribution carryforwards (f) $ — $ — $ 10 $ 10 Valuation allowance (e) — — (4 ) (4 ) Total charitable contribution carryforwards $ — $ — $ 6 $ 6 (a) Will begin to expire in 2029 . (b) Will begin to expire in 2023 . (c) Will begin to expire in 2029 . (d) Will begin to expire in 2016 . (e) See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. (f) Will begin to expire in 2016 . |
Schedule Of Changes To Unrecognized Tax Benefits And Related Interest | A reconciliation of the change in the unrecognized tax benefit balance during the years ended December 31, 2013 , 2014 , and 2015 , is as follows: Ameren Missouri Ameren Illinois Other Ameren Unrecognized tax benefits – January 1, 2013 $ 136 $ 13 $ 7 $ 156 Increases based on tax positions prior to 2013 — 2 5 7 Decreases based on tax positions prior to 2013 (122 ) (16 ) (5 ) (143 ) Increases based on tax positions related to 2013 16 — 53 (a) 69 Changes related to settlements with taxing authorities — — — — Decreases related to the lapse of statute of limitations 1 — — 1 Unrecognized tax benefits – December 31, 2013 $ 31 $ (1 ) $ 60 $ 90 Increases based on tax positions prior to 2014 1 1 4 6 Decreases based on tax positions prior to 2014 (32 ) (1 ) (9 ) (42 ) Increases based on tax positions related to 2014 — — — — Changes related to settlements with taxing authorities — — — — Increases related to the lapse of statute of limitations — — — — Unrecognized tax benefits – December 31, 2014 $ — $ (1 ) $ 55 $ 54 Increases based on tax positions prior to 2015 — 1 1 2 Decreases based on tax positions prior to 2015 — — (56 ) (a) (56 ) Increases based on tax positions related to 2015 — — — — Changes related to settlements with taxing authorities — — — — Increases related to the lapse of statute of limitations — — — — Unrecognized tax benefits – December 31, 2015 $ — $ — $ — $ — Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2013 $ 3 $ — $ 51 (a) $ 54 Total unrecognized tax benefits (detriments) that, if recognized, would affect the effective tax rates as of December 31, 2014 $ — $ (1 ) $ 53 (a) $ 52 Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2015 $ — $ — $ — $ — (a) Primarily due to tax positions relating to the New AER divestiture. The income statement impact of this unrecognized tax benefit was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. |
Reconciliation Of Changes In Liability For Interest On Unrecognized Tax Benefits | A reconciliation of the change in the liability for interest on unrecognized tax benefits during the years ended December 31, 2013 , 2014 , and 2015 , is as follows: Ameren Missouri Ameren Illinois Other Ameren Liability for interest – January 1, 2013 $ 8 $ 1 $ (3 ) $ 6 Interest charges (income) for 2013 (8 ) (1 ) 4 (5 ) Liability for interest – December 31, 2013 $ — $ — $ 1 $ 1 Interest charges (income) for 2014 — — (1 ) (1 ) Liability for interest – December 31, 2014 $ — $ — $ — $ — Interest charges (income) for 2015 — — — — Liability for interest – December 31, 2015 $ — $ — $ — $ — |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Related Party Transactions [Abstract] | |
Schedule of Related Party Transactions | The following table presents the impact on Ameren Missouri and Ameren Illinois of related party transactions for the years ended December 31, 2015 , 2014 , and 2013 . It is based primarily on the agreements discussed above and the money pool arrangements discussed in Note 4 – Short-term Debt and Liquidity. Agreement Income Statement Line Item Ameren Missouri Ameren Illinois Ameren Missouri power supply agreements Operating Revenues 2015 $ 15 $ (a) with Ameren Illinois 2014 5 (a) 2013 3 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2015 25 4 rent and facility services 2014 21 2 2013 21 1 Ameren Missouri and Ameren Illinois Operating Revenues 2015 2 (b) miscellaneous support services 2014 1 (b) 2013 1 3 Total Operating Revenues 2015 $ 42 $ 4 2014 27 2 2013 25 4 Ameren Illinois power supply Purchased Power 2015 $ (a) $ 15 agreements with Ameren Missouri 2014 (a) 5 2013 (a) 3 Ameren Illinois transmission Purchased Power 2015 (a) 2 services with ATXI 2014 (a) 2 2013 (a) 2 Total Purchased Power 2015 $ (a) $ 17 2014 (a) 7 2013 (a) 5 Ameren Services support services Other Operations and 2015 $ 131 $ 119 agreement Maintenance 2014 124 109 2013 116 93 Total Other Operations and 2015 $ 131 $ 119 Maintenance Expenses 2014 124 109 2013 116 93 Money pool borrowings (advances) Interest (Charges) 2015 $ (b) $ (b) Income 2014 (b) (b) 2013 (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies (
Commitments And Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule Of Insurance Coverage At Callaway Energy Center | The following table presents insurance coverage at Ameren Missouri’s Callaway energy center at December 31, 2015 . The property coverage and the nuclear liability coverage must be renewed on April 1 and January 1, respectively, of each year. Type and Source of Coverage Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers $ 375 $ — Pool participation 13,114 (a) 127 (b) $ 13,489 (c) $ 127 Property damage: Nuclear Electric Insurance Limited $ 2,750 (d) $ 27 (e) European Mutual Association for Nuclear Insurance 500 (f) — $ 3,250 $ 27 Replacement power: Nuclear Electric Insurance Limited $ 490 (g) $ 10 (e) (a) Provided through mandatory participation in an industrywide retrospective premium assessment program. (b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $375 million in the event of an incident at any licensed United States commercial reactor, payable at $19 million per year. (c) Limit of liability for each incident under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended. A company could be assessed up to $127 million per incident for each licensed reactor it operates, with a maximum of $19 million per incident to be paid in a calendar year for each reactor. This limit is subject to change to account for the effects of inflation and changes in the number of licensed reactors. (d) NEIL provides $2.25 billion in property damage, decontamination, and premature decommissioning insurance for both radiation and nonradiation events. An additional $500 million is provided for radiation events only for a total of $2.75 billion . (e) All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. (f) European Mutual Association for Nuclear Insurance provides $500 million in excess of the $2.75 billion and $2.25 billion property coverage for radiation and nonradiation events, respectively, provided by NEIL. (g) Provides replacement power cost insurance in the event of a prolonged accidental outage. Weekly indemnity is up to $4.5 million for 52 weeks, which commences after the first twelve weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter, for a total not exceeding the policy limit of $490 million . Nonradiation events are sub-limited to $328 million . |
Schedule Of Lease Obligations | We lease various facilities, office equipment, plant equipment, and rail cars under capital and operating leases. The following table presents our lease obligations at December 31, 2015 : 2016 2017 2018 2019 2020 After 5 Years Total Ameren: (a) Minimum capital lease payments (b) $ 33 $ 33 $ 32 $ 32 $ 32 $ 329 $ 491 Less amount representing interest 27 27 26 25 25 73 203 Present value of minimum capital lease payments $ 6 $ 6 $ 6 $ 7 $ 7 $ 256 $ 288 Operating leases (c) 14 13 12 12 11 30 92 Total lease obligations $ 20 $ 19 $ 18 $ 19 $ 18 $ 286 $ 380 Ameren Missouri: Minimum capital lease payments (b) $ 33 $ 33 $ 32 $ 32 $ 32 $ 329 $ 491 Less amount representing interest 27 27 26 25 25 73 203 Present value of minimum capital lease payments $ 6 $ 6 $ 6 $ 7 $ 7 $ 256 $ 288 Operating leases (c) 12 11 11 11 10 29 84 Total lease obligations $ 18 $ 17 $ 17 $ 18 $ 17 $ 285 $ 372 Ameren Illinois: Operating leases (c) $ 1 $ 1 $ 1 $ 1 $ 1 $ 1 $ 6 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (b) See Properties under Part I, Item 2, and Note 3 – Property and Plant, Net, of this report for additional information. (c) Amounts related to certain land-related leases have indefinite payment periods. The annual obligations of $3 million , $2 million , and $1 million for Ameren, Ameren Missouri, and Ameren Illinois for these items are included in the 2016 through 2020 columns, respectively. |
Schedule Of Rental Expense | The following table presents total rental expense included in operating expenses for the years ended December 31, 2015 , 2014 , and 2013 : 2015 2014 2013 Ameren (a) $ 36 $ 37 $ 32 Ameren Missouri 34 32 29 Ameren Illinois 28 25 21 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Schedule Of Estimated Purchased Commitments | December 31, 2015 . Ameren’s and Ameren Missouri’s purchased power commitments include a 102-megawatt power purchase agreement with a wind farm operator, which expires in 2024. Ameren’s and Ameren Illinois’ purchased power commitments include the Ameren Illinois power purchase agreements entered into as part of the IPA-administered power procurement process. Included in the Other column are minimum purchase commitments under contracts for equipment, design and construction, and meter reading services at December 31, 2015 . Coal Natural Gas (a) Nuclear Fuel Purchased Power (b) Methane Gas Other Total Ameren: (c) 2016 $ 664 $ 249 $ 51 $ 241 $ 3 $ 115 $ 1,323 2017 685 190 46 147 4 73 1,145 2018 204 127 68 72 5 55 531 2019 110 89 24 58 5 56 342 2020 — 43 51 58 6 57 215 Thereafter — 60 108 539 71 350 1,128 Total $ 1,663 $ 758 $ 348 $ 1,115 $ 94 $ 706 $ 4,684 Ameren Missouri: 2016 $ 664 $ 46 $ 51 $ 23 $ 3 $ 46 $ 833 2017 685 36 46 23 4 32 826 2018 204 24 68 23 5 28 352 2019 110 14 24 23 5 29 205 2020 — 10 51 23 6 30 120 Thereafter — 23 108 84 71 183 469 Total $ 1,663 $ 153 $ 348 $ 199 $ 94 $ 348 $ 2,805 Ameren Illinois: 2016 $ — $ 203 $ — $ 218 $ — $ 31 $ 452 2017 — 154 — 124 — 25 303 2018 — 103 — 49 — 24 176 2019 — 75 — 35 — 27 137 2020 — 33 — 35 — 27 95 Thereafter — 37 — 455 — 167 659 Total $ — $ 605 $ — $ 916 $ — $ 301 $ 1,822 (a) Includes amounts for generation and for distribution. (b) The purchased power amounts for Ameren and Ameren Illinois include agreements through 2032 for renewable energy credits with various renewable energy suppliers. The agreements contain a provision that allows Ameren Illinois to reduce the quantity purchased in the event that Ameren Illinois would not be able to recover the costs associated with the renewable energy credits. (c) Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Schedule Of Asbestos-Related Litigation Pending Lawsuits | he following table presents the pending asbestos-related lawsuits filed against Ameren Missouri and Ameren Illinois as of December 31, 2015 : Ameren Missouri Ameren Illinois Total (a) 26 38 48 (a) Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. |
Divestiture Transactions and 46
Divestiture Transactions and Discontinued Operations (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures | The following table presents the components of discontinued operations in Ameren's consolidated statement of income (loss) for the years ended December 31, 2015, 2014, and 2013: Year ended 2015 2014 2013 Operating revenues $ — $ 1 $ 1,037 Operating benefits (expenses) 1 (2 ) (1,207 ) (a) Operating income (loss) 1 (1 ) (170 ) Other income (loss) — — (1 ) Interest charges — — (39 ) Income (loss) before income taxes 1 (1 ) (210 ) Income tax (expense) benefit 50 — (13 ) Income (loss) from discontinued operations, net of taxes $ 51 $ (1 ) $ (223 ) (a) Includes a $201 million pretax loss on disposal relating to the New AER divestiture. The following table presents the carrying amounts of the components of assets and liabilities of Ameren's discontinued operations, which consist primarily of AROs and related deferred income tax assets associated with the abandoned Meredosia and Hutsonville energy centers, at December 31, 2015 and 2014: December 31, 2015 December 31, 2014 Assets of discontinued operations Accumulated deferred income taxes, net $ 14 $ 15 Total assets of discontinued operations $ 14 $ 15 Liabilities of discontinued operations Accounts payable and other current obligations $ 1 $ 1 Asset retirement obligations (a) 28 32 Total liabilities of discontinued operations $ 29 $ 33 (a) Ameren is demolishing the Hutsonville energy center and expects to demolish the Meredosia energy center beginning in 2016. |
Segment Information (Tables)
Segment Information (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Segment Reporting Information, Profit (Loss) [Abstract] | |
Schedule Of Segment Reporting Information, By Segment | The following table presents information about the reported revenues and specified items reflected in Ameren’s net income attributable to Ameren common shareholders and capital expenditures from continuing operations for the years ended December 31, 2015 , 2014 , and 2013 , and total assets in continuing operations as of December 31, 2015 , 2014 , and 2013 : Ameren Missouri Ameren Illinois Other Intersegment Eliminations Consolidated 2015 External revenues $ 3,566 $ 2,462 $ 70 $ — $ 6,098 Intersegment revenues 43 4 2 (49 ) — Depreciation and amortization 492 295 9 — 796 Interest and dividend income 28 12 1 — 41 Interest charges 219 131 5 — 355 Income taxes 209 127 27 — 363 Net income attributable to Ameren common shareholders from continuing operations 352 214 13 — 579 Capital expenditures 622 918 377 (a) — 1,917 Total assets (c) 13,851 8,903 1,139 (267 ) 23,626 (b) 2014 External revenues $ 3,526 $ 2,496 $ 31 $ — $ 6,053 Intersegment revenues 27 2 2 (31 ) — Depreciation and amortization 473 263 9 — 745 Interest and dividend income 28 7 2 — 37 Interest charges 211 112 18 — 341 Income taxes 229 143 5 — 377 Net income (loss) attributable to Ameren common shareholders from continuing operations 390 201 (4 ) — 587 Capital expenditures 747 835 203 (a) — 1,785 Total assets (c) 13,474 8,204 799 (203 ) 22,274 (b) 2013 External revenues $ 3,516 $ 2,307 $ 15 $ — $ 5,838 Intersegment revenues 25 4 2 (31 ) — Depreciation and amortization 454 243 9 — 706 Interest and dividend income 27 2 1 — 30 Interest charges 210 143 45 — 398 Income taxes (benefit) 242 110 (41 ) — 311 Net income (loss) attributable to Ameren common shareholders from continuing operations 395 160 (43 ) — 512 Capital expenditures 648 701 30 (a) — 1,379 Total assets (c) 12,867 7,397 711 (233 ) 20,742 (b) (a) Includes the elimination of intercompany transfers. (b) Excludes total assets from discontinued operations of $14 million , $15 million , and $165 million as of December 31, 2015 , 2014 , and 2013 , respectively. (c) Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs and balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. |
Selected Quarterly Information
Selected Quarterly Information (Tables) | 12 Months Ended |
Dec. 31, 2015 | |
Selected Quarterly Financial Information [Abstract] | |
Summary Of Selected Quarterly Information | SELECTED QUARTERLY INFORMATION (Unaudited) (In millions, except per share amounts) Ameren 2015 2014 Quarter ended (a) March 31 June 30 September 30 December 31 March 31 June 30 September 30 December 31 Operating revenues $ 1,556 $ 1,401 $ 1,833 $ 1,308 $ 1,594 $ 1,419 $ 1,670 $ 1,370 Operating income 256 237 626 140 246 322 561 125 Net income 110 151 345 30 98 150 295 49 Net income attributable to Ameren common shareholders – continuing operations $ 108 $ 98 $ 343 $ 30 $ 97 $ 150 $ 294 $ 46 Net income (loss) attributable to Ameren common shareholders – discontinued operations — 52 — (1 ) (1 ) (1 ) (1 ) 2 Net income attributable to Ameren common shareholders $ 108 $ 150 $ 343 $ 29 $ 96 $ 149 $ 293 $ 48 Earnings per common share – basic – continuing operations $ 0.45 $ 0.40 $ 1.42 $ 0.12 $ 0.40 $ 0.62 $ 1.21 $ 0.19 Earnings (loss) per common share – basic – discontinued operations — 0.21 — — — (0.01 ) — 0.01 Earnings per common share – basic $ 0.45 $ 0.61 $ 1.42 $ 0.12 $ 0.40 $ 0.61 $ 1.21 $ 0.20 Earnings per common share – diluted – continuing operations $ 0.45 $ 0.40 $ 1.41 $ 0.12 $ 0.40 $ 0.62 $ 1.20 $ 0.19 Earnings (loss) per common share – diluted – discontinued operations — 0.21 — — — (0.01 ) — 0.01 Earnings per common share – diluted $ 0.45 $ 0.61 $ 1.41 $ 0.12 $ 0.40 $ 0.61 $ 1.20 $ 0.20 (a) The sum of quarterly amounts, including per share amounts, may not equal amounts reported for year-to-date periods. This is because of the effects of rounding and the changes in the number of weighted-average diluted shares outstanding each period. Ameren Missouri Quarter ended Operating Revenues Operating Income Net Income (Loss) Net Income (Loss) Available to Common Shareholder March 31, 2015 $ 800 $ 115 $ 42 $ 41 March 31, 2014 817 119 48 47 June 30, 2015 884 146 62 61 June 30, 2014 900 243 127 126 September 30, 2015 1,171 423 240 239 September 30, 2014 1,097 394 223 222 December 31, 2015 754 58 11 11 December 31, 2014 739 29 (5 ) (5 ) Ameren Illinois Quarter ended Operating Revenues Operating Income Net Income Net Income Available to Common Shareholder March 31, 2015 $ 745 $ 120 $ 54 $ 53 March 31, 2014 774 120 54 53 June 30, 2015 513 83 32 31 June 30, 2014 519 75 29 28 September 30, 2015 655 189 98 98 September 30, 2014 572 158 75 75 December 31, 2015 553 74 33 32 December 31, 2014 633 97 46 45 |
Summary Of Significant Accoun49
Summary Of Significant Accounting Policies (Narrative) (Details) shares in Millions, people in Millions, customer in Millions, $ in Millions | 12 Months Ended | |||
Dec. 31, 2015USD ($)mi²customerpeopleshares | Dec. 31, 2014USD ($)shares | Dec. 31, 2013USD ($)shares | ||
Accounting Policies [Line Items] | ||||
Assumed Settlement of Performance Share Units | shares | 1 | 1.8 | 1.9 | |
Average performance share units excluded from calculation | 0 | 0 | 0 | |
Goodwill | $ 411 | $ 411 | ||
Deferred Income Taxes and Other Assets, Current | 352 | |||
Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Unamortized Debt Issuance Expense | [1] | (18) | (17) | |
Capital contribution from parent | 25 | 15 | ||
Goodwill | $ 411 | 411 | ||
Public Utilities, Area Serviced | mi² | 40,000 | |||
Public Utilities, Estimated Population of Service Territory | people | 3.1 | |||
Deferred Income Taxes and Other Assets, Current | 160 | |||
Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Unamortized Debt Issuance Expense | [1] | $ (19) | (18) | |
Capital contribution from parent | 224 | 215 | $ 4 | |
Noncash Or Part Noncash Capital Contribution From Parent | $ 38 | 9 | $ 0 | |
Public Utilities, Area Serviced | mi² | 24,000 | |||
Public Utilities, Estimated Population of Service Territory | people | 2.8 | |||
Return of capital to parent | $ 0 | (215) | ||
Deferred Income Taxes and Other Assets, Current | $ 49 | |||
Minimum | ||||
Accounting Policies [Line Items] | ||||
Percent of average depreciable cost | 3.00% | 3.00% | 3.00% | |
Maximum | ||||
Accounting Policies [Line Items] | ||||
Percent of average depreciable cost | 4.00% | 4.00% | 4.00% | |
Power | Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Public Utilities, Number of Customers | customer | 1.2 | |||
Power | Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Public Utilities, Number of Customers | customer | 1.2 | |||
Natural Gas | Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Public Utilities, Number of Customers | customer | 0.8 | |||
Natural Gas | Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Public Utilities, Number of Customers | customer | 0.1 | |||
FAC | Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Sharing Level For Fac | 95.00% | |||
New Accounting Pronouncement, Early Adoption, Effect [Member] | ||||
Accounting Policies [Line Items] | ||||
Unamortized Debt Issuance Expense | $ 43 | $ 35 | ||
New Accounting Pronouncement, Early Adoption, Effect [Member] | Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Unamortized Debt Issuance Expense | 18 | 17 | ||
New Accounting Pronouncement, Early Adoption, Effect [Member] | Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Unamortized Debt Issuance Expense | $ 19 | $ 18 | ||
[1] | Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies for additional information. |
Summary Of Significant Accoun50
Summary Of Significant Accounting Policies (Schedule Of Material And Supplies) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Accounting Policies [Line Items] | |||
Fuel | [1] | $ 173 | $ 134 |
Gas stored underground | 97 | 127 | |
Other materials and supplies | 268 | 263 | |
Total materials and supplies | 538 | 524 | |
Union Electric Company | |||
Accounting Policies [Line Items] | |||
Fuel | [1] | 173 | 134 |
Gas stored underground | 10 | 16 | |
Other materials and supplies | 204 | 197 | |
Total materials and supplies | 387 | 347 | |
Ameren Illinois Company | |||
Accounting Policies [Line Items] | |||
Fuel | [1] | 0 | 0 |
Gas stored underground | 87 | 111 | |
Other materials and supplies | 64 | 66 | |
Total materials and supplies | $ 151 | $ 177 | |
[1] | (a)Consists of coal, oil, and propane. |
Summary Of Significant Accoun51
Summary Of Significant Accounting Policies (Schedule Of Rates Used For Allowance For Funds Used During Construction) (Details) | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Union Electric Company | |||
Accounting Policies [Line Items] | |||
Allowance for funds used during construction, rate | 7.00% | 7.00% | 8.00% |
Ameren Illinois Company | |||
Accounting Policies [Line Items] | |||
Allowance for funds used during construction, rate | 6.00% | 2.00% | 8.00% |
Summary Of Significant Accoun52
Summary Of Significant Accounting Policies (Schedule Of Asset Retirement Obligations) (Details) - USD ($) | 12 Months Ended | ||||
Dec. 31, 2015 | Dec. 31, 2014 | ||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Balance | $ 396,000,000 | $ 369,000,000 | |||
Liabilities incurred | 3,000,000 | 2,000,000 | |||
Liabilities settled | (2,000,000) | (2,000,000) | |||
Accretion in period | [1] | 23,000,000 | 21,000,000 | ||
Change in estimates | 203,000,000 | [2] | 6,000,000 | [3] | |
Balance | 623,000,000 | [4] | 396,000,000 | ||
Other current liabilities | 379,000,000 | 434,000,000 | |||
Union Electric Company | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Balance | 389,000,000 | 366,000,000 | |||
Liabilities incurred | 3,000,000 | 2,000,000 | |||
Liabilities settled | (1,000,000) | (2,000,000) | |||
Accretion in period | [1] | 23,000,000 | 21,000,000 | ||
Change in estimates | 203,000,000 | [2] | 2,000,000 | [3] | |
Balance | 617,000,000 | [4] | 389,000,000 | ||
Other current liabilities | 120,000,000 | 117,000,000 | |||
Ameren Illinois Company | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Balance | 7,000,000 | [5] | 3,000,000 | ||
Liabilities incurred | 0 | 0 | |||
Liabilities settled | (1,000,000) | (1,000,000) | [6] | ||
Accretion in period | [1],[6] | 1,000,000 | 1,000,000 | ||
Change in estimates | 1,000,000 | [2],[6] | 4,000,000 | [3] | |
Balance | [5] | 6,000,000 | 7,000,000 | ||
Other current liabilities | 114,000,000 | $ 124,000,000 | |||
Callaway energy center decommissioning study [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Change in estimates | 99,000,000 | ||||
New CCR Rules Estimate [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Change in estimates | 100,000,000 | ||||
Other Estimate Changes [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Change in estimates | 4,000,000 | ||||
Asset Retirement Obligation Balance [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Other current liabilities | $ 5,000,000 | ||||
[1] | (b)Accretion expense was recorded as an increase to regulatory assets at Ameren Missouri and Ameren Illinois. | ||||
[2] | The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren and Ameren Missouri increased their AROs related to the decommissioning of the Callaway energy center by $99 million to reflect the 2015 cost study and funding analysis filed with the MoPSC, the extension of the estimated operating life until 2044, and a reduction in the discount rate assumption. See Note 10 – Callaway Energy Center for additional information. In addition, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $100 million to their AROs associated with CCR storage facilities. See Note 15 – Commitments and Contingencies for additional information. Ameren and Ameren Missouri also increased their AROs by $4 million due to a change in the estimated retirement dates of the Meramec and Rush Island energy centers as a result of the MoPSC's April 2015 electric rate order. | ||||
[3] | c)The ARO increase resulted in a corresponding increase recorded to "Property and Plant, Net." Ameren Illinois changed its fair value estimate for asbestos removal. | ||||
[4] | Balance included $5 million in "Other current liabilities" on the balance sheet as of December 31, 2015 | ||||
[5] | ncluded in “Other deferred credits and liabilities” on the balance sheet. | ||||
[6] | (a)Less than $1 million. |
Summary Of Significant Accoun53
Summary Of Significant Accounting Policies (Schedule Of Excise Taxes) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Accounting Policies [Line Items] | |||
Excise tax expense | $ 213 | $ 215 | $ 213 |
Union Electric Company | |||
Accounting Policies [Line Items] | |||
Excise tax expense | 156 | 151 | 152 |
Ameren Illinois Company | |||
Accounting Policies [Line Items] | |||
Excise tax expense | $ 57 | $ 64 | $ 61 |
Summary Of Significant Accoun54
Summary Of Significant Accounting Policies (Basic and Diluted Earnings Per Share Calculations) (Details) - shares shares in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Accounting Policies [Abstract] | |||
Assumed Settlement of Performance Share Units | 1 | 1.8 | 1.9 |
Average performance share units excluded from calculation | 0 | 0 | 0 |
Summary Of Significant Accoun55
Summary Of Significant Accounting Policies Summary of Significant Accounting Policies (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Supplemental Cash Flow Information [Line Items] | ||||
Interest Paid, Capitalized | $ 17 | $ 18 | $ 37 | |
Interest Paid, Net | 335 | 333 | 393 | |
Income Taxes Paid, Net | (15) | (27) | 8 | |
Continuing Operations | ||||
Supplemental Cash Flow Information [Line Items] | ||||
Interest Paid, Capitalized | 17 | 18 | 20 | |
Interest Paid, Net | [1] | 335 | 333 | 362 |
Income Taxes Paid, Net | (17) | (41) | 116 | |
Discontinued Operations | ||||
Supplemental Cash Flow Information [Line Items] | ||||
Interest Paid, Capitalized | 0 | 0 | 17 | |
Interest Paid, Net | [2] | 0 | 0 | 31 |
Income Taxes Paid, Net | $ 2 | $ 14 | $ (108) | |
[1] | (a)Net of $17 million, $18 million, and $20 million capitalized, respectively. | |||
[2] | (b)Net of $- million, $- million, and $17 million capitalized, respectively. |
Rate And Regulatory Matters Rat
Rate And Regulatory Matters Rate and Regulatory Matters (Narrative-Missouri) (Details) | 1 Months Ended | 3 Months Ended | 12 Months Ended | 36 Months Ended | ||
Apr. 30, 2015USD ($) | Mar. 31, 2016 | Dec. 31, 2015USD ($)MWhmi | Feb. 28, 2019USD ($) | Dec. 31, 2015USD ($) | Dec. 31, 2012 | |
Electric Distribution | Final Rate Order | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 122,000,000 | |||||
Public Utilities, Approved Return on Equity, Percentage | 9.53% | |||||
Public Utilities, Approved Equity Capital Structure, Percentage | 51.80% | |||||
Rate Base | $ 7,000,000,000 | |||||
Electric Distribution - Net Energy Costs [Member] | Final Rate Order | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 109,000,000 | |||||
Illinois Rivers Project [Member] | Ameren Transmission Company of Illinois [Member] | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Transmission Line Miles | mi | 7 | |||||
Mark Twain Project [Member] | Ameren Transmission Company of Illinois [Member] | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Transmission Line Miles | mi | 100 | |||||
MEEIA | Electric Distribution | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Energy Efficiency Program Spending | $ 134,000,000 | |||||
Net Shared Benefits | 174,000,000 | |||||
Incentive Award if Energy Efficiency Goals Are Achieved | $ 19,000,000 | |||||
Achieved Percentage of Energy Efficiency Earnings For Incentive Award | 100.00% | 100.00% | 100.00% | |||
Incentive Award if Energy Efficiency Goals Are Achieved, Period of Recognition | 3 years | |||||
Subsequent Event | MEEIA | Electric Distribution | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Energy Efficiency Program Spending | $ 158,000,000 | |||||
Incentive Award if Energy Efficiency Goals Are Achieved | $ 27,000,000 | |||||
Achieved Percentage of Energy Efficiency Earnings For Incentive Award | 100.00% | |||||
Incentive Award if Energy Efficiency Goals Are Achieved, Period of Recognition | 3 years | |||||
Incentive Award if Energy Efficiency Goals Are Achieved, Period | 3 years | |||||
Subsequent Event | Minimum | MEEIA | Electric Distribution | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Achieved Percentage of Energy Efficiency Earnings For Incentive Award | 25.00% | |||||
Noranda [Member] | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Revenue Requirement | $ 78,000,000 | $ 78,000,000 | ||||
Noranda Annual Megawatthours | MWh | 4,200,000 | |||||
Noranda Operating Capacity | 100.00% | |||||
Noranda Summer Base Rate | $ 45.78 | |||||
Noranda Winter Base Rate | $ 31.11 | |||||
Noranda [Member] | Subsequent Event | Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Customer pot lines Idled due to circuit failure | 2 | |||||
Number of customer pot lines | 3 | |||||
Number of days to file a rate case | 60 days | |||||
Number of Months to complete MoPSC Electric Service Proceeding | 11 months |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative-Illinois) (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2015USD ($)mi | Dec. 31, 2014USD ($) | |
Rate And Regulatory Matters [Line Items] | ||
Regulatory assets | $ 1,382 | $ 1,582 |
Current regulatory assets | 260 | 295 |
Ameren Illinois Company | ||
Rate And Regulatory Matters [Line Items] | ||
Regulatory assets | 771 | 883 |
Current regulatory assets | 167 | 129 |
Ameren Illinois Company | 2015 IEMA Revenue Requirement Reconciliation [Member] | IEIMA | Electric Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Regulatory assets | 62 | |
Ameren Illinois Company | 2014 IEMA Revenue Requirement Reconciliation [Member] | IEIMA | Electric Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Current regulatory assets | 103 | |
Ameren Illinois Company | 2013 IEMA Revenue Requirement Reconciliation [Member] | IEIMA | Electric Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Current regulatory assets | $ 65 | |
Ameren Illinois Company | Final Rate Order | Gas Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 45 | |
Public Utilities, Approved Return on Equity, Percentage | 9.60% | |
Public Utilities, Approved Equity Capital Structure, Percentage | 50.00% | |
Rate base | $ 1,200 | |
Ameren Illinois Company | Final Rate Order | Electric Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Public Utilities, Approved Rate Increase (Decrease), Amount | 15 | |
Disallowed costs associated with debt redemption | 15 | |
Allowed Costs Associated with Debt Redemption | 11 | |
Ameren Illinois Company | Final Rate Order | IEIMA | Electric Distribution | ||
Rate And Regulatory Matters [Line Items] | ||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 106 | |
Ameren Transmission Company of Illinois [Member] | Spoon River Project [Member] | ||
Rate And Regulatory Matters [Line Items] | ||
Transmission Line Miles | mi | 46 |
Rate And Regulatory Matters R58
Rate And Regulatory Matters Rate and Regulatory Matters (Narrative-Federal) (Details) - USD ($) $ in Millions | 1 Months Ended | 12 Months Ended | ||
Feb. 28, 2015 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Rate And Regulatory Matters [Line Items] | ||||
Current regulatory liabilities | $ 80 | $ 106 | ||
Provision for Callaway construction and operating license | $ 69 | $ 0 | ||
Midwest Independent Transmission System Operator, Inc [Member] | Administrative Law Judge [Member] | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Approved Return on Equity, Percentage | 10.32% | |||
Midwest Independent Transmission System Operator, Inc [Member] | Pending Ferc Case [Member] | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Approved Return on Equity, Percentage | 12.38% | |||
Customer Requested Rate on Equity | 8.67% | 9.15% | ||
Basis point reduction in FERC allowed base return on common equity | 0.50% | |||
Current regulatory liabilities | $ 45 | |||
Ameren Illinois Company | ||||
Rate And Regulatory Matters [Line Items] | ||||
Current regulatory liabilities | 39 | 84 | ||
Ameren Illinois Company | Midwest Independent Transmission System Operator, Inc [Member] | Pending Ferc Case [Member] | ||||
Rate And Regulatory Matters [Line Items] | ||||
Current regulatory liabilities | 32 | |||
Union Electric Company | ||||
Rate And Regulatory Matters [Line Items] | ||||
Current regulatory liabilities | 28 | 18 | ||
Provision for Callaway construction and operating license | 69 | $ 0 | $ 0 | |
New Nuclear Energy Center COL [Member] | ||||
Rate And Regulatory Matters [Line Items] | ||||
Provision for Callaway construction and operating license | 69 | |||
New Nuclear Energy Center COL [Member] | Union Electric Company | ||||
Rate And Regulatory Matters [Line Items] | ||||
Investments in Power and Distribution Projects | 69 | |||
Provision for Callaway construction and operating license | 69 | |||
Final Rate Order | Ameren Illinois Company | ||||
Rate And Regulatory Matters [Line Items] | ||||
Payments for Legal Settlements | $ 8 |
Rate And Regulatory Matters (Sc
Rate And Regulatory Matters (Schedule Of Regulatory Assets And Liabilities) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | $ 260 | $ 295 | |
Regulatory assets | 1,382 | 1,582 | |
Current regulatory liabilities | 80 | 106 | |
Regulatory liabilities | 1,905 | 1,850 | |
Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | 89 | 163 | |
Regulatory assets | 605 | 695 | |
Current regulatory liabilities | 28 | 18 | |
Regulatory liabilities | 1,172 | 1,147 | |
Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | 167 | 129 | |
Regulatory assets | 771 | 883 | |
Current regulatory liabilities | 39 | 84 | |
Regulatory liabilities | 732 | 703 | |
Under-Recovered FAC | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[2] | 37 | 128 |
Under-Recovered FAC | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[2] | 37 | 128 |
Under-Recovered FAC | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[2] | 0 | 0 |
Under-Recovered Illinois Electric Power Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 3 | 2 |
Under-Recovered Illinois Electric Power Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 0 | 0 |
Under-Recovered Illinois Electric Power Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 3 | 2 |
Under-Recovered PGA | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 8 | 20 |
Under-Recovered PGA | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 0 | 0 |
Under-Recovered PGA | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [3] | 8 | 20 |
MTM Derivative Losses | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [4] | 74 | 74 |
Regulatory assets | [4] | 190 | 158 |
MTM Derivative Losses | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [4] | 29 | 32 |
Regulatory assets | [4] | 15 | 14 |
MTM Derivative Losses | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [4] | 45 | 42 |
Regulatory assets | [4] | 175 | 144 |
Energy Efficiency Rider | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [5] | 23 | 3 |
Regulatory liabilities | [5] | 36 | 39 |
Energy Efficiency Rider | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [5] | 23 | 3 |
Regulatory liabilities | [5] | 0 | 0 |
Energy Efficiency Rider | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [5] | 0 | 0 |
Regulatory liabilities | [5] | 36 | 39 |
IEIMA | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[6] | 103 | 65 |
Regulatory assets | [1],[6] | 62 | 101 |
IEIMA | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[6] | 0 | 0 |
Regulatory assets | [1],[6] | 0 | 0 |
IEIMA | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[6] | 103 | 65 |
Regulatory assets | [1],[6] | 62 | 101 |
FERC Revenue Requirement Reconciliation | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[7] | 12 | 3 |
Regulatory assets | [1],[7] | 11 | 12 |
Current regulatory liabilities | [7] | 0 | 11 |
FERC Revenue Requirement Reconciliation | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[7] | 0 | 0 |
Regulatory assets | [1],[7] | 0 | 0 |
Current regulatory liabilities | [7] | 0 | 0 |
FERC Revenue Requirement Reconciliation | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory assets | [1],[7] | 8 | 0 |
Regulatory assets | [1],[7] | 5 | 8 |
Current regulatory liabilities | [7] | 0 | 11 |
Pension And Postretirement Benefit Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [8] | 297 | 423 |
Pension And Postretirement Benefit Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [8] | 95 | 148 |
Pension And Postretirement Benefit Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [8] | 202 | 275 |
Income Taxes | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [9] | 258 | 256 |
Regulatory liabilities | [10] | 42 | 55 |
Income Taxes | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [9] | 254 | 253 |
Regulatory liabilities | [10] | 36 | 41 |
Income Taxes | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [9] | 4 | 3 |
Regulatory liabilities | [10] | 6 | 14 |
Asset Retirement Obligation | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [11] | 4 | 5 |
Regulatory liabilities | [11] | 167 | 182 |
Asset Retirement Obligation | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [11] | 0 | 0 |
Regulatory liabilities | [11] | 167 | 182 |
Asset Retirement Obligation | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [11] | 4 | 5 |
Regulatory liabilities | [11] | 0 | 0 |
Callaway Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[12] | 32 | 36 |
Callaway Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[12] | 32 | 36 |
Callaway Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[12] | 0 | 0 |
Unamortized Loss On Reacquired Debt | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[13] | 138 | 152 |
Unamortized Loss On Reacquired Debt | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[13] | 69 | 72 |
Unamortized Loss On Reacquired Debt | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[13] | 69 | 80 |
Recoverable Costs Contaminated Facilities | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [14] | 230 | 251 |
Recoverable Costs Contaminated Facilities | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [14] | 0 | 0 |
Recoverable Costs Contaminated Facilities | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [14] | 230 | 251 |
Storm Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[15] | 9 | 3 |
Storm Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[15] | 0 | 0 |
Storm Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[15] | 9 | 3 |
Demand-Side Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[16] | 31 | 44 |
Demand-Side Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[16] | 31 | 44 |
Demand-Side Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[16] | 0 | 0 |
Reserve For Workers' Compensation Liabilities | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [17] | 13 | 14 |
Reserve For Workers' Compensation Liabilities | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [17] | 6 | 7 |
Reserve For Workers' Compensation Liabilities | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [17] | 7 | 7 |
Credit Facilities Fees | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [18] | 4 | 5 |
Credit Facilities Fees | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [18] | 4 | 5 |
Credit Facilities Fees | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [18] | 0 | 0 |
Construction Accounting For Pollution Control Equipment | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[19] | 20 | 21 |
Construction Accounting For Pollution Control Equipment | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[19] | 20 | 21 |
Construction Accounting For Pollution Control Equipment | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[19] | 0 | 0 |
Solar Rebates | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[20] | 74 | 88 |
Solar Rebates | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[20] | 74 | 88 |
Solar Rebates | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | [1],[20] | 0 | 0 |
Other | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | 9 | 13 | |
Regulatory liabilities | 3 | 0 | |
Other | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | 5 | 7 | |
Regulatory liabilities | 2 | 0 | |
Other | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory assets | 4 | 6 | |
Regulatory liabilities | 1 | 0 | |
Over-Recovered FAC | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [2] | 9 | 0 |
Over-Recovered FAC | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [2] | 9 | 0 |
Over-Recovered FAC | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [2] | 0 | 0 |
Over-Recovered Illinois Electric Power Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 6 | 26 |
Over-Recovered Illinois Electric Power Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 0 | 0 |
Over-Recovered Illinois Electric Power Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 6 | 26 |
Over-Recovered PGA | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 3 | 27 |
Over-Recovered PGA | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 3 | 2 |
Over-Recovered PGA | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [3] | 0 | 25 |
MTM Derivative Gains | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [4] | 17 | 17 |
MTM Derivative Gains | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [4] | 16 | 16 |
MTM Derivative Gains | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [4] | 1 | 1 |
Refund Reserves for FERC Orders and Audit Findings | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [21] | 45 | 25 |
Refund Reserves for FERC Orders and Audit Findings | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [21] | 0 | 0 |
Refund Reserves for FERC Orders and Audit Findings | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Current regulatory liabilities | [21] | 32 | 21 |
Uncertain tax positions tracker | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [22] | 6 | 7 |
Uncertain tax positions tracker | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [22] | 6 | 7 |
Uncertain tax positions tracker | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [22] | 0 | 0 |
Removal Costs | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [23] | 1,605 | 1,529 |
Removal Costs | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [23] | 933 | 886 |
Removal Costs | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [23] | 671 | 643 |
Bad Debt Rider | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [24] | 6 | 7 |
Bad Debt Rider | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [24] | 0 | 0 |
Bad Debt Rider | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [24] | 6 | 7 |
Pension And Postretirement Benefit Costs Tracker | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [25] | 19 | 24 |
Pension And Postretirement Benefit Costs Tracker | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [25] | 19 | 24 |
Pension And Postretirement Benefit Costs Tracker | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [25] | 0 | 0 |
Renewable Energy Credits | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [26] | 12 | 1 |
Renewable Energy Credits | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [26] | 0 | 1 |
Renewable Energy Credits | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [26] | 12 | 0 |
Storm Tracker | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [27] | 9 | 6 |
Storm Tracker | Union Electric Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [27] | 9 | 6 |
Storm Tracker | Ameren Illinois Company | |||
Rate And Regulatory Matters [Line Items] | |||
Regulatory liabilities | [27] | $ 0 | $ 0 |
[1] | (a)These assets earn a return. | ||
[2] | (b)Under-recovered or over-recovered fuel costs to be recovered or refunded through the FAC. Specific accumulation periods aggregate the under-recovered or over-recovered costs over four months, any related adjustments that occur over the following four months, and the recovery from or refund to customers that occurs over the next eight months. | ||
[3] | (c)Under-recovered or over-recovered costs from utility customers. Amounts will be recovered from, or refunded to, customers within one year of the deferral. | ||
[4] | (d)Deferral of commodity-related derivative MTM losses or gains. See Note 7 – Derivative Financial Instruments for additional information. | ||
[5] | (e)The Ameren Missouri balance relates to the MEEIA. Beginning in January 2014, the MEEIA rider allowed Ameren Missouri to collect from or refund to customers any annual difference in the actual amounts incurred and the amounts collected from customers for the MEEIA program costs and its net shared benefits. Under the MEEIA rider, collections from or refunds to customers occur one year after the program costs and lost revenues are incurred. The Ameren Illinois balance relates to a regulatory tracking mechanism to recover its electric and natural gas costs associated with developing, implementing, and evaluating customer energy efficiency and demand response programs. Any under-recovery or over-recovery will be collected from or refunded to customers over the 12 months following the plan year. | ||
[6] | (f)The difference between Ameren Illinois' annual revenue requirement calculated under the IEIMA's performance-based formula ratemaking framework and the revenue requirement included in customer rates for that year. Subject to ICC approval, these amounts will be collected from or refunded to customers with interest within two years. | ||
[7] | (g)Ameren Illinois' and ATXI's annual revenue requirement reconciliation adjustments calculated pursuant to the FERC's electric transmission formula ratemaking framework. The under-recovery or over-recovery will be recovered from or refunded to customers within two years. | ||
[8] | (h)These costs are being amortized in proportion to the recognition of prior service costs (credits) and actuarial losses (gains) attributable to Ameren’s pension plan and postretirement benefit plans. See Note 11 – Retirement Benefits for additional information. | ||
[9] | (i)Tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate changes. This will be recovered over the expected life of the related assets. | ||
[10] | (u)Unamortized portion of investment tax credits and reductions to deferred tax liabilities recorded at rates in excess of current statutory rates. The unamortized portion of investment tax credits and the reduction to deferred tax liabilities are being amortized over the expected life of the underlying assets. | ||
[11] | (j)Recoverable or refundable removal costs for AROs, including net realized and unrealized gains and losses related to the nuclear decommissioning trust fund investments. See Note 1 – Summary of Significant Accounting Policies – Asset Retirement Obligations and Investments. | ||
[12] | (k)Ameren Missouri’s Callaway energy center operations and maintenance expenses, property taxes, and carrying costs incurred between the plant in-service date and the date the plant was reflected in rates. These costs are being amortized over the remaining life of the energy center's original operating license through 2024. | ||
[13] | (l)Losses related to reacquired debt. These amounts are being amortized over the lives of the related new debt issuances or the original lives of the old debt issuances if no new debt was issued. | ||
[14] | (m)The recoverable portion of accrued environmental site liabilities that will be collected from electric and natural gas customers through ICC-approved cost recovery riders. The period of recovery will depend on the timing of remediation expenditures. See Note 15 – Commitments and Contingencies for additional information. | ||
[15] | (n)Storm costs from 2013 and 2015 deferred in accordance with the IEIMA. These costs are being amortized over five-year periods beginning in 2013 and 2015, respectively. | ||
[16] | (o)Demand-side costs incurred prior to implementation of the MEEIA in 2013, including the costs of developing, implementing, and evaluating customer energy efficiency and demand response programs. Costs incurred from May 2008 through September 2008 are being amortized over a 10-year period that began in March 2009. Costs incurred from October 2008 through December 2009 are being amortized until May 2017. Costs incurred from January 2010 through February 2011 are being amortized over a six-year period that began in August 2011. Costs incurred from March 2011 through July 2012 are being amortized over a six-year period that began in January 2013. Costs incurred from August 2012 through December 2012 are being amortized over a six-year period that began in June 2015. | ||
[17] | (p)The period of recovery will depend on the timing of actual expenditures. | ||
[18] | (q)Ameren Missouri’s costs incurred to enter into and maintain the Missouri Credit Agreement. Additional costs were incurred in December 2014 to amend and restate the Missouri Credit Agreement. These costs are being amortized over the life of the credit facility, ending in December 2019, to construction work in progress, which will be depreciated when assets are placed into service. | ||
[19] | (r)The MoPSC’s May 2010 electric rate order allowed Ameren Missouri to record an allowance for funds used during construction for pollution control equipment at its Sioux energy center until the cost of that equipment was included in customer rates beginning in 2011. These costs are being amortized over the expected life of the Sioux energy center, which is currently through 2033. | ||
[20] | (s)Costs associated with Ameren Missouri's solar rebate program beginning in August 2012 to fulfill its renewable energy portfolio requirement. These costs are being amortized over three years, beginning in June 2015. | ||
[21] | (t)Estimated refunds to transmission customers related to FERC orders. See Ameren Illinois Electric Transmission Rate Refund and FERC Complaint Cases above. | ||
[22] | (v)The tracker is amortized over three years, beginning from the date the amounts are included in rates. See Note 13 – Income Taxes for additional information. | ||
[23] | (w)Estimated funds collected for the eventual dismantling and removal of plant from service, net of salvage value, upon retirement related to our rate-regulated operations. | ||
[24] | (x)A regulatory tracking mechanism for the difference between the level of bad debt incurred by Ameren Illinois under GAAP and the level of such costs included in electric and natural gas rates. The over-recovery relating to 2013 was refunded to customers from June 2014 through May 2015. The over-recovery relating to 2014 will be refunded to customers from June 2015 through May 2016. The over-recovery relating to 2015 will be refunded to customers from June 2016 through May 2017. | ||
[25] | (y)A regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over three to five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. | ||
[26] | (z)The Ameren Missouri balance includes the costs of renewable energy credits to fulfill Ameren Missouri's renewable energy portfolio requirement from August 2012 through December 2013, which were less than the amount included in rates. These costs are being amortized over three years beginning in June 2015. The Ameren Illinois balance includes funds collected from customers for the purchase of renewable energy credits through IPA procurements for distributed generation. The balance will be amortized as renewable energy credits are purchased. | ||
[27] | (aa)A regulatory tracking mechanism at Ameren Missouri for the difference between the level of storm costs incurred in a particular year and the level of such costs included in rates. For periods prior to December 2014, the MoPSC's April 2015 electric rate order directed the amortization to occur over five years, beginning in June 2015. For periods after December 2014, the amortization period will be determined in a future electric rate case. The April 2015 MoPSC order did not approve the continued use of the regulatory tracking mechanisms for storm costs. |
Property And Plant, Net (Schedu
Property And Plant, Net (Schedule Of Property And Plant, Net) (Details) $ in Millions | Dec. 31, 2015USD ($)equipment | Dec. 31, 2014USD ($) | |
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | $ 27,603 | $ 26,198 |
Accumulated depreciation and amortization | [1] | 10,347 | 9,759 |
Property and plant, before construction work in progress | [1] | 17,256 | 16,439 |
Property, Plant and Equipment, Net | [1] | $ 18,799 | 17,424 |
Number of combustion turbine electric generation equipment under capital lease agreements | equipment | 2 | ||
Number of capital lease agreements | equipment | 2 | ||
Capital lease agreements, gross asset value | $ 233 | ||
Total accumulated depreciation, capital lease agreements | 72 | 66 | |
Held-to-maturity Securities | 288 | 294 | |
Electric | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | 25,161 | 23,913 |
Gas | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | 2,442 | 2,285 |
Nuclear Fuel | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | [1] | 275 | 209 |
Other Energy | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | [1] | 1,268 | 776 |
Union Electric Company | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | 17,966 | 17,483 |
Accumulated depreciation and amortization | [1] | 7,460 | 7,086 |
Property and plant, before construction work in progress | [1] | 10,506 | 10,397 |
Property, Plant and Equipment, Net | [1] | 11,183 | 10,867 |
Union Electric Company | Electric | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | 17,521 | 17,052 |
Union Electric Company | Gas | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | [1] | 445 | 431 |
Union Electric Company | Nuclear Fuel | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | [1] | 275 | 209 |
Union Electric Company | Other Energy | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | [1] | 402 | 261 |
Ameren Illinois Company | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 9,250 | 8,371 | |
Accumulated depreciation and amortization | 2,632 | 2,422 | |
Property and plant, before construction work in progress | 6,618 | 5,949 | |
Property, Plant and Equipment, Net | 6,848 | 6,165 | |
Ameren Illinois Company | Electric | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 7,253 | 6,517 | |
Ameren Illinois Company | Gas | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 1,997 | 1,854 | |
Ameren Illinois Company | Nuclear Fuel | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | 0 | 0 | |
Ameren Illinois Company | Other Energy | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | 230 | 216 | |
Other | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 387 | 344 | |
Accumulated depreciation and amortization | 255 | 251 | |
Property and plant, before construction work in progress | 132 | 93 | |
Property, Plant and Equipment, Net | 768 | 392 | |
Other | Electric | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 387 | 344 | |
Other | Gas | |||
Property, Plant and Equipment [Line Items] | |||
Property and plant, at original cost | 0 | 0 | |
Other | Nuclear Fuel | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | 0 | 0 | |
Other | Other Energy | |||
Property, Plant and Equipment [Line Items] | |||
Construction work in progress | $ 636 | $ 299 | |
[1] | (a)Amounts in Ameren and Ameren Missouri include two CTs under separate capital lease agreements. The gross cumulative asset value of those agreements was $233 million at December 31, 2015 and 2014. The total accumulated depreciation associated with the two CTs was $72 million and $66 million at December 31, 2015 and 2014, respectively. In addition, Ameren Missouri has investments in debt securities, which were classified as held-to-maturity and recorded in "Other assets", related to the two CTs from the city of Bowling Green and Audrain County. As of December 31, 2015 and 2014, the carrying value of these debt securities was $288 million and $294 million, respectively. |
Property And Plant, Net (Accrue
Property And Plant, Net (Accrued Capital Expenditures) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Property, Plant and Equipment [Line Items] | ||||
Accrued capital expenditures | [1] | $ 235 | $ 181 | $ 175 |
Union Electric Company | ||||
Property, Plant and Equipment [Line Items] | ||||
Accrued capital expenditures | 85 | 72 | 74 | |
Ameren Illinois Company | ||||
Property, Plant and Equipment [Line Items] | ||||
Accrued capital expenditures | 92 | 59 | 86 | |
Nuclear Fuel | ||||
Property, Plant and Equipment [Line Items] | ||||
Accrued capital expenditures | [1] | 16 | 13 | 8 |
Nuclear Fuel | Union Electric Company | ||||
Property, Plant and Equipment [Line Items] | ||||
Accrued capital expenditures | $ 16 | $ 13 | $ 8 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Short-Term Debt And Liquidity62
Short-Term Debt And Liquidity (Narrative) (Details) | 12 Months Ended | |
Dec. 31, 2015USD ($)lender | Dec. 31, 2014 | |
Illinois Credit Agreement 2012 | Maximum | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 1,300,000,000 | |
Illinois Credit Agreement 2012 | Ameren Illinois Company | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 800,000,000 | |
Actual debt-to-capital ratio | 0.47 | |
Missouri Credit Agreement 2012 | Maximum | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 1,200,000,000 | |
Missouri Credit Agreement 2012 | Union Electric Company | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 800,000,000 | |
Actual debt-to-capital ratio | 0.49 | |
Credit Agreements 2012 | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 1,800,000,000 | |
Covenant terms, default provisions, maximum indebtedness | 75,000,000 | |
Multiyear Credit Facility | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility, maximum borrowing capacity | $ 2,100,000,000 | |
Number of lenders | lender | 24 | |
Line of credit facility, maximum borrowing capacity, per lender | $ 115,000,000 | |
Actual debt-to-capital ratio | 0.51 | |
Minimum ratio of consolidated funds from operations plus interest expense to consolidated interest expense as of balance sheet date | 2.0 to 1.0 | |
Line of Credit Facility, Commitment Fee Amount | $ 100,000,000 | |
Multiyear Credit Facility | Maximum | ||
Line of Credit Facility [Line Items] | ||
Actual debt-to-capital ratio | 0.65 | |
Utilities | ||
Line of Credit Facility [Line Items] | ||
Short Term Debt, Weighted Average Interest Rate During Period | 0.11% | 0.19% |
Short-Term Debt And Liquidity63
Short-Term Debt And Liquidity (Schedule Of Maximum Aggregate Amount Available On Credit Agreements) (Details) $ in Millions | Dec. 31, 2015USD ($) |
Illinois Credit Agreement 2012 | Parent Company | |
Line of Credit Facility [Line Items] | |
Line of credit facility, maximum borrowing capacity | $ 500 |
Illinois Credit Agreement 2012 | Ameren Illinois Company | |
Line of Credit Facility [Line Items] | |
Line of credit facility, maximum borrowing capacity | 800 |
Missouri Credit Agreement 2012 | Parent Company | |
Line of Credit Facility [Line Items] | |
Line of credit facility, maximum borrowing capacity | 700 |
Missouri Credit Agreement 2012 | Union Electric Company | |
Line of Credit Facility [Line Items] | |
Line of credit facility, maximum borrowing capacity | $ 800 |
Short-Term Debt And Liquidity S
Short-Term Debt And Liquidity Short-Term Debt And Liquidity (Commercial Paper) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | ||
Commercial Paper | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 767 | $ 639 | |
Commercial paper outstanding | $ 301 | $ 714 | |
Weighted average interest rate | 0.55% | 0.36% | |
Peak short-term borrowings | [1] | $ 1,108 | $ 910 |
Peak short-term borrowings interest rate | 0.91% | 0.75% | |
Parent Company | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 721 | $ 423 | |
Weighted average interest rate | 0.57% | 0.36% | |
Peak short-term borrowings | [1] | $ 874 | $ 625 |
Peak short-term borrowings interest rate | 0.91% | 0.75% | |
Parent Company | Commercial Paper | |||
Line of Credit Facility [Line Items] | |||
Commercial paper outstanding | $ 301 | $ 585 | |
Union Electric Company | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 42 | $ 110 | |
Weighted average interest rate | 0.50% | 0.38% | |
Peak short-term borrowings | [1] | $ 294 | $ 495 |
Peak short-term borrowings interest rate | 0.60% | 0.70% | |
Ameren Illinois Company | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 4 | $ 165 | |
Weighted average interest rate | 0.44% | 0.32% | |
Peak short-term borrowings | [1] | $ 48 | $ 300 |
Peak short-term borrowings interest rate | 0.60% | 0.60% | |
Ameren Illinois Company | Commercial Paper | |||
Line of Credit Facility [Line Items] | |||
Commercial paper outstanding | $ 0 | $ 32 | |
Ameren Missouri [Member] | Commercial Paper | |||
Line of Credit Facility [Line Items] | |||
Commercial paper outstanding | $ 0 | $ 97 | |
[1] | (a)The timing of peak commercial paper issuances varies by company, and therefore the peak amounts presented by company might not equal the Ameren Consolidated peak commercial paper issuances for the period. |
Long-Term Debt And Equity Fin65
Long-Term Debt And Equity Financings (Narrative) (Details) - USD ($) | 1 Months Ended | 3 Months Ended | 12 Months Ended | |||||||||||||||
Dec. 31, 2014 | Jun. 30, 2014 | May. 31, 2014 | Apr. 30, 2014 | Jan. 31, 2014 | Dec. 31, 2015 | Jun. 30, 2015 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | Mar. 31, 2016 | May. 15, 2014 | Oct. 31, 2013 | ||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt Default Provision Excess | $ 25,000,000 | |||||||||||||||||
Preferred stock, authorized | 100,000,000 | 100,000,000 | ||||||||||||||||
Preferred stock, par value | $ 0.01 | $ 0.01 | ||||||||||||||||
Preferred stock, shares outstanding | 0 | 0 | ||||||||||||||||
Common stock, shares authorized | 400,000,000 | 400,000,000 | 400,000,000 | 400,000,000 | ||||||||||||||
Repayments of Other Long-term Debt | $ 120,000,000 | $ 697,000,000 | $ 399,000,000 | |||||||||||||||
Union Electric Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Preferred stock, authorized | 7,500,000 | 7,500,000 | ||||||||||||||||
Preferred stock, par value | $ 1 | $ 1 | ||||||||||||||||
Common stock, shares authorized | 150,000,000 | 150,000,000 | 150,000,000 | 150,000,000 | ||||||||||||||
Repayments of Other Long-term Debt | $ 120,000,000 | $ 109,000,000 | 249,000,000 | |||||||||||||||
Ameren Illinois Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Preferred stock, authorized | 2,600,000 | 2,600,000 | ||||||||||||||||
Common stock, shares authorized | 45,000,000 | 45,000,000 | 45,000,000 | 45,000,000 | ||||||||||||||
Repayments of Other Long-term Debt | $ 0 | $ 163,000,000 | 150,000,000 | |||||||||||||||
Debt instrument face amount | [1] | $ 1,000,000 | ||||||||||||||||
Common stock equity to capitalization ratio | 51.00% | 51.00% | ||||||||||||||||
Ameren Illinois Company | Environmental Improvement And Pollution Control Revenue Bonds | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Redemptions of long-term debt | 163,000,000 | |||||||||||||||||
Parent Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Common stock, shares authorized | 8,600,000 | 4,000,000 | ||||||||||||||||
Repayments of Other Long-term Debt | $ 0 | 425,000,000 | $ 0 | |||||||||||||||
Ameren Missouri and Ameren Illinois | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Bonds interest rate assumption | 5.00% | 5.00% | ||||||||||||||||
Dividend rate on preferred shares, percentage | 6.00% | |||||||||||||||||
Senior Unsecured Notes270 due 2020 [Member] | Parent Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Long-term debt interest rate | 2.70% | 2.70% | ||||||||||||||||
Senior Unsecured Notes270 due 2020 [Member] | Parent Company | Unsecured Debt [Member] | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | $ 0 | $ 350,000,000 | $ 350,000,000 | 0 | ||||||||||||||
Long-term debt interest rate | 2.70% | 2.70% | ||||||||||||||||
Proceeds from issuance of secured debt | $ 348,000,000 | |||||||||||||||||
Senior Unsecured Notes365 due 2026 [Member] | Parent Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Long-term debt interest rate | 3.65% | 3.65% | ||||||||||||||||
Senior Unsecured Notes365 due 2026 [Member] | Parent Company | Unsecured Debt [Member] | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | 0 | $ 350,000,000 | $ 350,000,000 | 0 | ||||||||||||||
Long-term debt interest rate | 3.65% | 3.65% | ||||||||||||||||
Proceeds from issuance of secured debt | $ 347,000,000 | |||||||||||||||||
Series1993570 Due2024 [Member] | Ameren Illinois Company | Environmental Improvement And Pollution Control Revenue Bonds | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [2] | 1,000,000 | $ 1,000,000 | |||||||||||||||
Senior Unsecured Notes8875 Due2014 [Member] | Parent Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Repayments of Other Long-term Debt | $ 425,000,000 | |||||||||||||||||
Long-term debt interest rate | 8.875% | |||||||||||||||||
5.40% Senior secured notes due 2016 | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [3] | 260,000,000 | $ 260,000,000 | $ 260,000,000 | 260,000,000 | |||||||||||||
Long-term debt interest rate | 5.40% | 5.40% | ||||||||||||||||
Senior Secured Notes, 3.65%, Due 2045 [Member] | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | 0 | [3] | $ 250,000,000 | $ 250,000,000 | 0 | [3] | ||||||||||||
Long-term debt interest rate | 3.65% | 3.65% | ||||||||||||||||
Proceeds from issuance of secured debt | $ 247,000,000 | |||||||||||||||||
Senior Secured Notes 4.75% Due2015 [Member] | Union Electric Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Repayments of Other Long-term Debt | $ 114,000,000 | |||||||||||||||||
Long-term debt interest rate | 4.75% | |||||||||||||||||
Senior Secured Notes 4.75% Due2015 [Member] | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [3] | 114,000,000 | $ 0 | $ 0 | 114,000,000 | |||||||||||||
Long-term debt interest rate | 4.75% | 4.75% | ||||||||||||||||
Senior Secured Notes, 3.50%, Due 2024 [Member] | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | $ 350,000,000 | |||||||||||||||||
Long-term debt interest rate | 3.50% | |||||||||||||||||
Proceeds from issuance of secured debt | $ 348,000,000 | |||||||||||||||||
5.50% Senior secured notes due 2014 | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Long-term debt interest rate | 5.50% | |||||||||||||||||
Redemptions of long-term debt | $ 104,000,000 | |||||||||||||||||
Senior Secured Notes 4.80% Due 2043 | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [4] | 280,000,000 | $ 280,000,000 | $ 280,000,000 | 280,000,000 | |||||||||||||
Long-term debt interest rate | 4.80% | 4.80% | ||||||||||||||||
1993 5.45% Series due 2028 | Union Electric Company | Environmental Improvement And Pollution Control Revenue Bonds | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [2] | $ 1,000,000 | $ 1,000,000 | |||||||||||||||
Long-term debt interest rate | 5.45% | 5.45% | ||||||||||||||||
Senior Secured Notes, 4.15%, Due 2046 [Member] | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | 0 | [4] | $ 250,000,000 | $ 250,000,000 | 0 | [4] | ||||||||||||
Long-term debt interest rate | 4.15% | 4.15% | ||||||||||||||||
Proceeds from issuance of secured debt | $ 245,000,000 | |||||||||||||||||
Senior Secured Notes, 4.30%, Due 2044 [Member] [Member] | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | $ 250,000,000 | |||||||||||||||||
Long-term debt interest rate | 4.30% | |||||||||||||||||
Proceeds from issuance of secured debt | $ 246,000,000 | |||||||||||||||||
Senior Secured Notes, 3 Point 25, Due 2025 [Member] | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [4] | 300,000,000 | $ 300,000,000 | [5] | $ 300,000,000 | [5] | 300,000,000 | |||||||||||
Long-term debt interest rate | 3.25% | 3.25% | ||||||||||||||||
Proceeds from issuance of secured debt | 298,000,000 | |||||||||||||||||
Senior Secured Notes, 2.70%, Due 2022 | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [4],[5] | 400,000,000 | $ 400,000,000 | $ 400,000,000 | 400,000,000 | |||||||||||||
Long-term debt interest rate | 2.70% | 2.70% | ||||||||||||||||
3.90% Senior secured notes due 2042 | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [3],[6] | 485,000,000 | $ 485,000,000 | $ 485,000,000 | 485,000,000 | |||||||||||||
Long-term debt interest rate | 3.90% | 3.90% | ||||||||||||||||
Series 1993 5.90% Due 2023 | Ameren Illinois Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [2] | $ 1,000,000 | $ 1,000,000 | |||||||||||||||
Long-term debt interest rate | 5.90% | 5.90% | ||||||||||||||||
Series 1993 5.90% Due 2023 | Ameren Illinois Company | Environmental Improvement And Pollution Control Revenue Bonds | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | [7] | $ 1,000,000 | $ 1,000,000 | [2] | $ 1,000,000 | [2] | $ 1,000,000 | |||||||||||
Long-term debt interest rate | 5.90% | 5.90% | ||||||||||||||||
Redemptions of long-term debt | [8] | $ 32,000,000 | ||||||||||||||||
Minimum | Ameren Illinois Company | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Common stock equity to capitalization ratio | 30.00% | 30.00% | ||||||||||||||||
Subsequent Event | 5.40% Senior secured notes due 2016 | Union Electric Company | Secured Debt | ||||||||||||||||||
Long-Term Debt And Equity Financings [Line Items] | ||||||||||||||||||
Debt instrument face amount | $ 260,000,000 | |||||||||||||||||
Long-term debt interest rate | 5.40% | |||||||||||||||||
[1] | These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. Less than $1 million principal amount of the bonds remains outstanding. | |||||||||||||||||
[2] | These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. | |||||||||||||||||
[3] | These notes are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under the Ameren Missouri mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Missouri senior secured notes currently outstanding, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2042. | |||||||||||||||||
[4] | These notes are collaterally secured by mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois senior secured notes currently outstanding, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2024. | |||||||||||||||||
[5] | Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur, and so long as any of the 9.75% senior secured notes due 2018, 6.25% senior secured notes due 2018 and 6.125% senior secured notes due 2017 are outstanding, Ameren Illinois will not optionally redeem, purchase or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions; therefore, a release date will not occur so long as any of these notes remain outstanding. | |||||||||||||||||
[6] | Ameren Missouri has agreed that so long as any of the 3.90% senior secured notes due 2042 are outstanding, Ameren Missouri will not permit a release date to occur, and so long as any of the 6.70% senior secured notes due 2019, 6.00% senior secured notes due 2018 and 8.45% senior secured notes due 2039 are outstanding, Ameren Missouri will not optionally redeem, purchase, or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions. | |||||||||||||||||
[7] | These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. They are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. | |||||||||||||||||
[8] | Less than $1 million principal amount of the bonds remains outstanding after redemption. |
Long-Term Debt And Equity Fin66
Long-Term Debt And Equity Financings (Schedule Of Long-Term Debt Outstanding) (Details) - USD ($) | 12 Months Ended | ||||||||
Dec. 31, 2015 | Jun. 30, 2015 | Dec. 31, 2014 | May. 31, 2014 | May. 15, 2014 | Jan. 31, 2014 | ||||
Debt Instrument [Line Items] | |||||||||
Less: Maturities due within one year | $ (395,000,000) | $ (120,000,000) | |||||||
Long-term Debt, Net | 6,880,000,000 | 6,085,000,000 | |||||||
Parent Company | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt, gross | 700,000,000 | 0 | |||||||
Unamortized Debt Issuance Expense | [1] | (6,000,000) | 0 | ||||||
Long-term Debt, Net | $ 694,000,000 | 0 | |||||||
Parent Company | Senior Unsecured Notes270 due 2020 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt interest rate | 2.70% | ||||||||
Long-term debt maturity date | 2,020 | ||||||||
Parent Company | Senior Unsecured Notes365 due 2026 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt interest rate | 3.65% | ||||||||
Long-term debt maturity date | 2,026 | ||||||||
Parent Company | 8.875% Senior unsecured notes due 2014 | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt interest rate | 8.875% | ||||||||
Ameren Illinois Company | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [2] | $ 1,000,000 | |||||||
Long-term debt, gross | $ 2,496,000,000 | 2,246,000,000 | |||||||
Unamortized Debt Issuance Expense | [1] | (18,000,000) | (17,000,000) | ||||||
Less: Unamortized discount and premium | 7,000,000 | 5,000,000 | |||||||
Less: Maturities due within one year | (129,000,000) | 0 | |||||||
Long-term Debt, Net | 2,342,000,000 | 2,224,000,000 | |||||||
Union Electric Company | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt, gross | 4,135,000,000 | 4,005,000,000 | |||||||
Unamortized Debt Issuance Expense | [1] | (19,000,000) | (18,000,000) | ||||||
Less: Unamortized discount and premium | 6,000,000 | 6,000,000 | |||||||
Less: Maturities due within one year | (266,000,000) | (120,000,000) | |||||||
Long-term Debt, Net | 3,844,000,000 | 3,861,000,000 | |||||||
Union Electric Company | Senior Secured Notes 4.75% Due2015 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt interest rate | 4.75% | ||||||||
Union Electric Company | City Of Bowling Green Capital Lease Peno Creek Ct | |||||||||
Debt Instrument [Line Items] | |||||||||
Capital lease obligations | $ 48,000,000 | 54,000,000 | |||||||
Long-term debt maturity date | 2,022 | ||||||||
Union Electric Company | Audrain County Capital Lease Audrain County Ct | |||||||||
Debt Instrument [Line Items] | |||||||||
Capital lease obligations | $ 240,000,000 | 240,000,000 | |||||||
Long-term debt maturity date | 2,023 | ||||||||
Unsecured Debt [Member] | Parent Company | Senior Unsecured Notes270 due 2020 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | $ 350,000,000 | 0 | |||||||
Long-term debt interest rate | 2.70% | ||||||||
Unsecured Debt [Member] | Parent Company | Senior Unsecured Notes365 due 2026 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | $ 350,000,000 | 0 | |||||||
Long-term debt interest rate | 3.65% | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.20% Due 2016 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [3] | $ 54,000,000 | 54,000,000 | ||||||
Long-term debt interest rate | 6.20% | ||||||||
Long-term debt maturity date | 2,016 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.25% Due 2016 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 75,000,000 | 75,000,000 | ||||||
Long-term debt interest rate | 6.25% | ||||||||
Long-term debt maturity date | 2,016 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.125% Due 2017 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4],[5] | $ 250,000,000 | 250,000,000 | ||||||
Long-term debt interest rate | 6.125% | ||||||||
Long-term debt maturity date | 2,017 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.25% Due 2018 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4],[5] | $ 144,000,000 | 144,000,000 | ||||||
Long-term debt interest rate | 6.25% | ||||||||
Long-term debt maturity date | 2,018 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 9.75% Due 2018 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4],[5] | $ 313,000,000 | 313,000,000 | ||||||
Long-term debt interest rate | 9.75% | ||||||||
Long-term debt maturity date | 2,018 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes, 2.70%, Due 2022 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4],[5] | $ 400,000,000 | 400,000,000 | ||||||
Long-term debt interest rate | 2.70% | ||||||||
Long-term debt maturity date | 2,022 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes, 3 Point 25, Due 2025 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 300,000,000 | [5] | 300,000,000 | |||||
Long-term debt interest rate | 3.25% | ||||||||
Long-term debt maturity date | 2,025 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.125% Due 2028 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 60,000,000 | 60,000,000 | ||||||
Long-term debt interest rate | 6.125% | ||||||||
Long-term debt maturity date | 2,028 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.70% Due 2036 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 61,000,000 | 61,000,000 | ||||||
Long-term debt interest rate | 6.70% | ||||||||
Long-term debt maturity date | 2,036 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 6.70% Due 2036 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [3] | $ 42,000,000 | 42,000,000 | ||||||
Long-term debt interest rate | 6.70% | ||||||||
Long-term debt maturity date | 2,036 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes 4.80% Due 2043 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 280,000,000 | 280,000,000 | ||||||
Long-term debt interest rate | 4.80% | ||||||||
Long-term debt maturity date | 2,043 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes430 Due2044 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [4] | $ 250,000,000 | 250,000,000 | ||||||
Long-term debt interest rate | 4.30% | ||||||||
Long-term debt maturity date | 2,044 | ||||||||
Secured Debt | Ameren Illinois Company | Senior Secured Notes, 4.15%, Due 2046 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | $ 250,000,000 | 0 | [4] | ||||||
Long-term debt interest rate | 4.15% | ||||||||
Secured Debt | Ameren Illinois Company | Series 1993 5.90% Due 2023 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [6] | $ 1,000,000 | |||||||
Long-term debt interest rate | 5.90% | ||||||||
Secured Debt | Union Electric Company | 5.50% Senior secured notes due 2014 | |||||||||
Debt Instrument [Line Items] | |||||||||
Long-term debt interest rate | 5.50% | ||||||||
Secured Debt | Union Electric Company | Senior Secured Notes 4.75% Due2015 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 0 | 114,000,000 | ||||||
Long-term debt interest rate | 4.75% | ||||||||
Long-term debt maturity date | 2,015 | ||||||||
Secured Debt | Union Electric Company | 5.40% Senior secured notes due 2016 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 260,000,000 | 260,000,000 | ||||||
Long-term debt interest rate | 5.40% | ||||||||
Long-term debt maturity date | 2,016 | ||||||||
Secured Debt | Union Electric Company | 6.40% Senior secured notes due 2017 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 425,000,000 | 425,000,000 | ||||||
Long-term debt interest rate | 6.40% | ||||||||
Long-term debt maturity date | 2,017 | ||||||||
Secured Debt | Union Electric Company | 6.00% Senior secured notes due 2018 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7],[8] | $ 179,000,000 | 179,000,000 | ||||||
Long-term debt interest rate | 6.00% | ||||||||
Long-term debt maturity date | 2,018 | ||||||||
Secured Debt | Union Electric Company | 5.10% Senior secured notes due 2018 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 199,000,000 | 199,000,000 | ||||||
Long-term debt interest rate | 5.10% | ||||||||
Long-term debt maturity date | 2,018 | ||||||||
Secured Debt | Union Electric Company | 6.70% Senior secured notes due 2019 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7],[8] | $ 329,000,000 | 329,000,000 | ||||||
Long-term debt interest rate | 6.70% | ||||||||
Long-term debt maturity date | 2,019 | ||||||||
Secured Debt | Union Electric Company | 5.10% Senior secured notes due 2019 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 244,000,000 | 244,000,000 | ||||||
Long-term debt interest rate | 5.10% | ||||||||
Long-term debt maturity date | 2,019 | ||||||||
Secured Debt | Union Electric Company | 5.00% Senior secured notes due 2020 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 85,000,000 | 85,000,000 | ||||||
Long-term debt interest rate | 5.00% | ||||||||
Long-term debt maturity date | 2,020 | ||||||||
Secured Debt | Union Electric Company | Senior Secured Notes350 Due2024 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 350,000,000 | 350,000,000 | ||||||
Long-term debt interest rate | 3.50% | ||||||||
Long-term debt maturity date | 2,024 | ||||||||
Secured Debt | Union Electric Company | 5.50% Senior secured notes due 2034 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 184,000,000 | 184,000,000 | ||||||
Long-term debt interest rate | 5.50% | ||||||||
Long-term debt maturity date | 2,034 | ||||||||
Secured Debt | Union Electric Company | 5.30% Senior secured notes due 2037 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7] | $ 300,000,000 | 300,000,000 | ||||||
Long-term debt interest rate | 5.30% | ||||||||
Long-term debt maturity date | 2,037 | ||||||||
Secured Debt | Union Electric Company | 8.45% Senior secured notes due 2039 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7],[8] | $ 350,000,000 | 350,000,000 | ||||||
Long-term debt interest rate | 8.45% | ||||||||
Long-term debt maturity date | 2,039 | ||||||||
Secured Debt | Union Electric Company | 3.90% Senior secured notes due 2042 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [7],[8] | $ 485,000,000 | 485,000,000 | ||||||
Long-term debt interest rate | 3.90% | ||||||||
Long-term debt maturity date | 2,042 | ||||||||
Secured Debt | Union Electric Company | Senior Secured Notes, 3.65%, Due 2045 [Member] | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | $ 250,000,000 | 0 | [7] | ||||||
Long-term debt interest rate | 3.65% | ||||||||
Long-term debt maturity date | 2,045 | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Ameren Illinois Company | Series 1993 5.90% Due 2023 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [9] | $ 1,000,000 | [6] | 1,000,000 | |||||
Long-term debt interest rate | 5.90% | ||||||||
Long-term debt maturity date | 2,023 | ||||||||
Redemption price, percentage | 100.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Ameren Illinois Company | Series 1994 A 5.70% Due 2024 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [2] | $ 1,000,000 | 1,000,000 | ||||||
Long-term debt interest rate | 5.70% | ||||||||
Long-term debt maturity date | 2,024 | ||||||||
Redemption price, percentage | 100.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Ameren Illinois Company | Series C-1 1993 5.95% Due 2026 | |||||||||
Debt Instrument [Line Items] | |||||||||
Redemption price, percentage | 100.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Ameren Illinois Company | Series B-1 1993 Due 2028 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [10],[11] | $ 17,000,000 | 17,000,000 | ||||||
Long-term debt maturity date | 2,028 | ||||||||
Redemption price, percentage | 100.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Union Electric Company | 1992 Series due 2022 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [11],[12] | $ 47,000,000 | 47,000,000 | ||||||
Long-term debt maturity date | 2,022 | ||||||||
Debt instrument, interest rate, maximum | 18.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Union Electric Company | 1993 5.45% Series due 2028 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [6] | $ 1,000,000 | |||||||
Long-term debt interest rate | 5.45% | ||||||||
Long-term debt maturity date | 2,028 | ||||||||
Redemption price, percentage | 100.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Union Electric Company | 1998 Series A due 2033 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [11],[12] | $ 60,000,000 | 60,000,000 | ||||||
Long-term debt maturity date | 2,033 | ||||||||
Debt instrument, interest rate, maximum | 18.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Union Electric Company | 1998 Series B due 2033 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [11],[12] | $ 50,000,000 | 50,000,000 | ||||||
Long-term debt maturity date | 2,033 | ||||||||
Debt instrument, interest rate, maximum | 18.00% | ||||||||
Environmental Improvement And Pollution Control Revenue Bonds | Union Electric Company | 1998 Series C due 2033 | |||||||||
Debt Instrument [Line Items] | |||||||||
Debt instrument face amount | [11],[12] | $ 50,000,000 | $ 50,000,000 | ||||||
Long-term debt maturity date | 2,033 | ||||||||
Debt instrument, interest rate, maximum | 18.00% | ||||||||
[1] | Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies for additional information. | ||||||||
[2] | These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. Less than $1 million principal amount of the bonds remains outstanding. | ||||||||
[3] | These notes are collaterally secured by first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. The notes have a fall-away lien provision, and Ameren Illinois could cause these notes to become unsecured at any time by redeeming the pollution control bonds 5.90% Series 1993 due 2023 (of which less than $1 million remains outstanding). | ||||||||
[4] | These notes are collaterally secured by mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois senior secured notes currently outstanding, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2024. | ||||||||
[5] | Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur, and so long as any of the 9.75% senior secured notes due 2018, 6.25% senior secured notes due 2018 and 6.125% senior secured notes due 2017 are outstanding, Ameren Illinois will not optionally redeem, purchase or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions; therefore, a release date will not occur so long as any of these notes remain outstanding. | ||||||||
[6] | These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. | ||||||||
[7] | These notes are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under the Ameren Missouri mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Missouri senior secured notes currently outstanding, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2042. | ||||||||
[8] | Ameren Missouri has agreed that so long as any of the 3.90% senior secured notes due 2042 are outstanding, Ameren Missouri will not permit a release date to occur, and so long as any of the 6.70% senior secured notes due 2019, 6.00% senior secured notes due 2018 and 8.45% senior secured notes due 2039 are outstanding, Ameren Missouri will not optionally redeem, purchase, or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions. | ||||||||
[9] | These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. They are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. | ||||||||
[10] | The bonds are callable at 100% of par value. | ||||||||
[11] | The interest rates, and the periods during which such rates apply, vary depending on our selection of defined rate modes. Maximum interest rates could reach 18% depending on the series of bonds. The bonds are callable at 100% of par value. The average interest rates for 2015 and 2014 were as follows: 2015 2014Ameren Missouri 1992 Series due 20220.06% 0.10%Ameren Missouri 1998 Series A due 20330.24% 0.26%Ameren Missouri 1998 Series B due 20330.24% 0.27%Ameren Missouri 1998 Series C due 20330.24% 0.26%Ameren Illinois 1993 Series B-1 due 20280.49% 0.21% | ||||||||
[12] | These bonds are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture and have a fall-away lien provision similar to that of Ameren Missouri's senior secured notes. The bonds are also backed by an insurance guarantee policy. |
Long-Term Debt And Equity Fin67
Long-Term Debt And Equity Financings (Schedule Of Average Interest Rates) (Details) | 12 Months Ended | |
Dec. 31, 2015 | Dec. 31, 2014 | |
1992 Series due 2022 | Union Electric Company | ||
Debt Instrument [Line Items] | ||
Debt instrument, interest rate during period | 0.06% | 0.10% |
1998 Series A due 2033 | Union Electric Company | ||
Debt Instrument [Line Items] | ||
Debt instrument, interest rate during period | 0.24% | 0.26% |
1998 Series B due 2033 | Union Electric Company | ||
Debt Instrument [Line Items] | ||
Debt instrument, interest rate during period | 0.24% | 0.27% |
1998 Series C due 2033 | Union Electric Company | ||
Debt Instrument [Line Items] | ||
Debt instrument, interest rate during period | 0.24% | 0.26% |
Series B-1 1993 Due 2028 | Ameren Illinois Company | ||
Debt Instrument [Line Items] | ||
Debt instrument, interest rate during period | 0.49% | 0.21% |
Secured Debt | 3.90% Senior secured notes due 2042 | Union Electric Company | ||
Debt Instrument [Line Items] | ||
Long-term debt interest rate | 3.90% |
Long-Term Debt And Equity Fin68
Long-Term Debt And Equity Financings (Schedule Of Maturities Of Long-Term Debt) (Details) $ in Millions | Dec. 31, 2015USD ($) | |
Debt Instrument [Line Items] | ||
2,015 | $ 395 | |
2,016 | 681 | |
2,017 | 840 | |
2,018 | 581 | |
2,019 | 442 | |
Thereafter | 4,392 | |
Total | 7,331 | |
Parent Company | ||
Debt Instrument [Line Items] | ||
2,019 | 350 | [1] |
Thereafter | 350 | [1] |
Total | 700 | [1] |
Debt Instrument, Unamortized Discount or Premium and Debt Issuance Costs | (6) | |
Union Electric Company | ||
Debt Instrument [Line Items] | ||
2,015 | 266 | [1] |
2,016 | 431 | [1] |
2,017 | 383 | [1] |
2,018 | 581 | [1] |
2,019 | 92 | [1] |
Thereafter | 2,382 | [1] |
Total | 4,135 | [1] |
Debt Instrument, Unamortized Discount or Premium and Debt Issuance Costs | 25 | |
Ameren Illinois Company | ||
Debt Instrument [Line Items] | ||
2,015 | 129 | [1] |
2,016 | 250 | [1] |
2,017 | 457 | [1] |
Thereafter | 1,660 | [1] |
Total | 2,496 | [1] |
Debt Instrument, Unamortized Discount or Premium and Debt Issuance Costs | $ 25 | |
[1] | Excludes unamortized discount and premium and debt issuance costs of $6 million, $25 million, and $25 million at Ameren (parent), Ameren Missouri, and Ameren Illinois, respectively. |
Long-Term Debt And Equity Fin69
Long-Term Debt And Equity Financings (Schedule Of Outstanding Preferred Stock) (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | ||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, par value | $ 0.01 | ||
Preferred stock, authorized | 100,000,000 | ||
Preferred stock, shares outstanding | 0 | ||
Preferred stock, voluntary liquidation | $ 105.50 | ||
Union Electric Company and Ameren Illinois [Member] | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, issued | $ 142 | $ 142 | |
Union Electric Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, par value | $ 1 | ||
Preferred stock, authorized | 7,500,000 | ||
Preferred stock, issued | $ 80 | 80 | |
Union Electric Company | Par Value $100 [Member] | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, par value | $ 100 | ||
Preferred stock, authorized | 25,000,000 | ||
Union Electric Company | $3.50 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 3.50 | ||
Preferred stock, shares outstanding | 130,000 | ||
Preferred stock, redemption price per share | $ 110 | ||
Preferred stock, issued | $ 13 | 13 | |
Union Electric Company | $3.70 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 3.70 | ||
Preferred stock, shares outstanding | 40,000 | ||
Preferred stock, redemption price per share | $ 104.75 | ||
Preferred stock, issued | $ 4 | 4 | |
Union Electric Company | $4.00 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 4 | ||
Preferred stock, shares outstanding | 150,000 | ||
Preferred stock, redemption price per share | $ 105.625 | ||
Preferred stock, issued | $ 15 | 15 | |
Union Electric Company | $4.30 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 4.30 | ||
Preferred stock, shares outstanding | 40,000 | ||
Preferred stock, redemption price per share | $ 105 | ||
Preferred stock, issued | $ 4 | 4 | |
Union Electric Company | $4.50 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 4.50 | ||
Preferred stock, shares outstanding | 213,595 | ||
Preferred stock, redemption price per share | [1] | $ 110 | |
Preferred stock, issued | $ 21 | 21 | |
Union Electric Company | $4.56 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 4.56 | ||
Preferred stock, shares outstanding | 200,000 | ||
Preferred stock, redemption price per share | $ 102.47 | ||
Preferred stock, issued | $ 20 | 20 | |
Union Electric Company | $4.75 Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 4.75 | ||
Preferred stock, shares outstanding | 20,000 | ||
Preferred stock, redemption price per share | $ 102.176 | ||
Preferred stock, issued | $ 2 | 2 | |
Union Electric Company | $5.50 Series A | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, per-dollar amount | $ 5.50 | ||
Preferred stock, shares outstanding | 14,000 | ||
Preferred stock, redemption price per share | $ 110 | ||
Preferred stock, issued | $ 1 | 1 | |
Ameren Illinois Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, authorized | 2,600,000 | ||
Preferred stock, issued | $ 62 | 62 | |
Ameren Illinois Company | Par Value $100 [Member] | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Preferred stock, par value | $ 100 | ||
Preferred stock, authorized | 2,000,000 | ||
Ameren Illinois Company | 4.00% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.00% | ||
Preferred stock, shares outstanding | 144,275 | ||
Preferred stock, redemption price per share | $ 101 | ||
Preferred stock, issued | $ 14 | 14 | |
Ameren Illinois Company | 4.08% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.08% | ||
Preferred stock, shares outstanding | 45,224 | ||
Preferred stock, redemption price per share | $ 103 | ||
Preferred stock, issued | $ 5 | 5 | |
Ameren Illinois Company | 4.20% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.20% | ||
Preferred stock, shares outstanding | 23,655 | ||
Preferred stock, redemption price per share | $ 104 | ||
Preferred stock, issued | $ 2 | 2 | |
Ameren Illinois Company | 4.25% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.25% | ||
Preferred stock, shares outstanding | 50,000 | ||
Preferred stock, redemption price per share | $ 102 | ||
Preferred stock, issued | $ 5 | 5 | |
Ameren Illinois Company | 4.26% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.26% | ||
Preferred stock, shares outstanding | 16,621 | ||
Preferred stock, redemption price per share | $ 103 | ||
Preferred stock, issued | $ 2 | 2 | |
Ameren Illinois Company | 4.42% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.42% | ||
Preferred stock, shares outstanding | 16,190 | ||
Preferred stock, redemption price per share | $ 103 | ||
Preferred stock, issued | $ 2 | 2 | |
Ameren Illinois Company | 4.70% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.70% | ||
Preferred stock, shares outstanding | 18,429 | ||
Preferred stock, redemption price per share | $ 103 | ||
Preferred stock, issued | $ 2 | 2 | |
Ameren Illinois Company | 4.90% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.90% | ||
Preferred stock, shares outstanding | 73,825 | ||
Preferred stock, redemption price per share | $ 102 | ||
Preferred stock, issued | $ 7 | 7 | |
Ameren Illinois Company | 4.92% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 4.92% | ||
Preferred stock, shares outstanding | 49,289 | ||
Preferred stock, redemption price per share | $ 103.50 | ||
Preferred stock, issued | $ 5 | 5 | |
Ameren Illinois Company | 5.16% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 5.16% | ||
Preferred stock, shares outstanding | 50,000 | ||
Preferred stock, redemption price per share | $ 102 | ||
Preferred stock, issued | $ 5 | 5 | |
Ameren Illinois Company | 6.625% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 6.625% | ||
Preferred stock, shares outstanding | 124,274 | ||
Preferred stock, redemption price per share | $ 100 | ||
Preferred stock, issued | $ 12 | 12 | |
Ameren Illinois Company | 7.75% Series | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Dividend rate on preferred shares, percentage | 7.75% | ||
Preferred stock, shares outstanding | 4,542 | ||
Preferred stock, redemption price per share | $ 100 | ||
Preferred stock, issued | $ 1 | $ 1 | |
[1] | In the event of voluntary liquidation, $105.50 |
Long-Term Debt and Equity Fin70
Long-Term Debt and Equity Financings (Schedule of Debt Redemptions) (Details) - Ameren Illinois Company - USD ($) $ in Millions | 1 Months Ended | ||||
Jan. 31, 2014 | Dec. 31, 2015 | Dec. 31, 2014 | |||
Debt Instrument [Line Items] | |||||
Debt instrument face amount | [1] | $ 1 | |||
Secured Debt | Senior Secured Notes 9.75% Due 2018 | |||||
Debt Instrument [Line Items] | |||||
Debt instrument face amount | [2],[3] | $ 313 | $ 313 | ||
Secured Debt | Series 1993 5.90% Due 2023 | |||||
Debt Instrument [Line Items] | |||||
Debt instrument face amount | [4] | 1 | |||
Secured Debt | Senior Secured Notes 6.25% Due 2018 | |||||
Debt Instrument [Line Items] | |||||
Debt instrument face amount | [2],[3] | 144 | 144 | ||
Environmental Improvement And Pollution Control Revenue Bonds | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | 163 | ||||
Environmental Improvement And Pollution Control Revenue Bonds | Series 1993 5.90% Due 2023 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | [5] | 32 | |||
Debt instrument face amount | [6] | 1 | [4] | 1 | |
Environmental Improvement And Pollution Control Revenue Bonds | Series 1994 A 5.70% Due 2024 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | [5] | 36 | |||
Debt instrument face amount | [1] | $ 1 | $ 1 | ||
Environmental Improvement And Pollution Control Revenue Bonds | Series C-1 1993 5.95% Due 2026 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | 35 | ||||
Environmental Improvement And Pollution Control Revenue Bonds | Series C-2 1993 5.70% Due 2026 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | 8 | ||||
Environmental Improvement And Pollution Control Revenue Bonds | Series1998A 5.40% Due 2028 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | 19 | ||||
Environmental Improvement And Pollution Control Revenue Bonds | Series1998B 5.40% Due 2028 | |||||
Debt Instrument [Line Items] | |||||
Redemptions of long-term debt | $ 33 | ||||
[1] | These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. Less than $1 million principal amount of the bonds remains outstanding. | ||||
[2] | Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur, and so long as any of the 9.75% senior secured notes due 2018, 6.25% senior secured notes due 2018 and 6.125% senior secured notes due 2017 are outstanding, Ameren Illinois will not optionally redeem, purchase or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions; therefore, a release date will not occur so long as any of these notes remain outstanding. | ||||
[3] | These notes are collaterally secured by mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all property of the former IP and CIPS. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois senior secured notes currently outstanding, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2024. | ||||
[4] | These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. | ||||
[5] | Less than $1 million principal amount of the bonds remains outstanding after redemption. | ||||
[6] | These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. They are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. |
Long-Term Debt and Equity Fin71
Long-Term Debt and Equity Financings (Schedule of Required and Actual Debt Ratios) (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2015USD ($) | ||
Union Electric Company | ||
Debt Instrument [Line Items] | ||
Bonds Issuable Based On Coverage Ratio | $ 3,385 | [1] |
Preferred Stock Issuable Based On Coverage Ratio | 2,315 | |
Retired Bond Capacity | $ 946 | |
Union Electric Company | Actual Interest Coverage Ratio | ||
Debt Instrument [Line Items] | ||
Interest Coverage Ratio | 3.8 | |
Dividend Coverage Ratio | 104 | |
Ameren Illinois Company | ||
Debt Instrument [Line Items] | ||
Bonds Issuable Based On Coverage Ratio | $ 3,566 | [1],[2] |
Preferred Stock Issuable Based On Coverage Ratio | 203 | [3] |
Retired Bond Capacity | $ 204 | |
Ameren Illinois Company | Actual Interest Coverage Ratio | ||
Debt Instrument [Line Items] | ||
Interest Coverage Ratio | 6.3 | |
Dividend Coverage Ratio | 2.6 | |
Minimum | Union Electric Company | Required Dividend Coverage Ratio | ||
Debt Instrument [Line Items] | ||
Interest Coverage Ratio | 2 | [4] |
Dividend Coverage Ratio | 2.5 | [5] |
Minimum | Ameren Illinois Company | Required Dividend Coverage Ratio | ||
Debt Instrument [Line Items] | ||
Interest Coverage Ratio | 2 | [4] |
Dividend Coverage Ratio | 1.5 | [5] |
[1] | Amount of bonds issuable based either on required coverage ratios or unfunded property additions, whichever is more restrictive. The amounts shown also include bonds issuable based on retired bond capacity of $946 million and $204 million at Ameren Missouri and Ameren Illinois, respectively. | |
[2] | Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. The amount of bonds issuable by Ameren Illinois is also subject to the lien restrictions contained in the Illinois Credit Agreement. | |
[3] | Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinois' articles of incorporation. | |
[4] | Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. | |
[5] | Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. |
Other Income And Expenses (Othe
Other Income And Expenses (Other Income And Expenses) (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | [1] | $ 30 | $ 34 | $ 37 | |
Interest income on industrial development revenue bonds | [1] | 27 | 27 | 27 | |
Interest and dividend income | [1],[2] | 14 | 10 | 3 | |
Other | [1] | 3 | 8 | [3] | 2 |
Total miscellaneous income | [1] | 74 | 79 | 69 | |
Donations | [1] | 15 | 10 | 12 | |
Other | [1] | 15 | 12 | 14 | |
Total miscellaneous expense | [1] | 30 | 22 | 26 | |
Union Electric Company | |||||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | 22 | 32 | 31 | ||
Interest income on industrial development revenue bonds | 27 | 27 | 27 | ||
Interest and dividend income | 1 | 1 | 0 | ||
Other | 2 | 0 | 0 | ||
Total miscellaneous income | 52 | 60 | 58 | ||
Donations | 5 | 6 | 4 | ||
Other | 6 | 6 | 7 | ||
Total miscellaneous expense | 11 | 12 | 11 | ||
Ameren Illinois Company | |||||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | 8 | 2 | 6 | ||
Interest and dividend income | [2] | 12 | 7 | 2 | |
Other | 1 | 8 | [3] | 2 | |
Total miscellaneous income | 21 | 17 | 10 | ||
Donations | 5 | 4 | 4 | ||
Other | 7 | 4 | 5 | ||
Total miscellaneous expense | $ 12 | $ 8 | $ 9 | ||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. | ||||
[2] | Includes Ameren Illinois' interest income on the IEIMA revenue requirement reconciliation adjustment regulatory assets. | ||||
[3] | Includes Ameren Illinois' income earned in 2014 from customer-requested construction. |
Derivative Financial Instrume73
Derivative Financial Instruments (Open Gross Derivative Volumes By Commodity Type) (Details) lb in Thousands, gal in Millions, MWh in Millions, MMBTU in Millions | Dec. 31, 2015MWhgalMMBTUlb | Dec. 31, 2014MWhgalMMBTUlb | |
Fuel Oils | |||
Derivative [Line Items] | |||
Quantity | gal | [1] | 35 | 50 |
Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 181 | 136 | |
Power | |||
Derivative [Line Items] | |||
Quantity | MWh | 11 | 12 | |
Uranium | |||
Derivative [Line Items] | |||
Quantity | lb | 494 | 332 | |
Union Electric Company | Fuel Oils | |||
Derivative [Line Items] | |||
Quantity | gal | [1] | 35 | 50 |
Union Electric Company | Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 30 | 28 | |
Union Electric Company | Power | |||
Derivative [Line Items] | |||
Quantity | MWh | 1 | 1 | |
Union Electric Company | Uranium | |||
Derivative [Line Items] | |||
Quantity | lb | 494 | 332 | |
Ameren Illinois Company | Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 151 | 108 | |
Ameren Illinois Company | Power | |||
Derivative [Line Items] | |||
Quantity | MWh | 10 | 11 | |
[1] | Fuel oils consist of heating oil and ultra-low-sulfur diesel. |
Derivative Financial Instrume74
Derivative Financial Instruments (Derivative Instruments Carrying Value) (Details) - Not Designated As Hedging Instrument - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Derivative [Line Items] | |||
Derivative assets | [1] | $ 18 | $ 19 |
Derivative liabilities | [2] | 264 | 232 |
Fuel Oils | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 2 | ||
Fuel Oils | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 22 | 22 | |
Fuel Oils | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 7 | 7 | |
Natural Gas | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 1 | 2 | |
Natural Gas | Other assets | |||
Derivative [Line Items] | |||
Derivative assets | 1 | ||
Natural Gas | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 38 | 37 | |
Natural Gas | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 26 | 19 | |
Power | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 16 | 15 | |
Power | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 13 | 14 | |
Power | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 157 | 131 | |
Uranium | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 1 | 2 | |
Union Electric Company | |||
Derivative [Line Items] | |||
Derivative assets | [1] | 17 | 18 |
Derivative liabilities | [2] | 44 | 46 |
Union Electric Company | Fuel Oils | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 2 | ||
Union Electric Company | Fuel Oils | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 22 | 22 | |
Union Electric Company | Fuel Oils | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 7 | 7 | |
Union Electric Company | Natural Gas | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 1 | ||
Union Electric Company | Natural Gas | Other assets | |||
Derivative [Line Items] | |||
Derivative assets | 1 | ||
Union Electric Company | Natural Gas | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 6 | 6 | |
Union Electric Company | Natural Gas | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 8 | 6 | |
Union Electric Company | Power | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 16 | 15 | |
Union Electric Company | Power | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 3 | ||
Union Electric Company | Uranium | Other current liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 1 | 2 | |
Ameren Illinois Company | |||
Derivative [Line Items] | |||
Derivative assets | [1] | 1 | 1 |
Derivative liabilities | [2] | 220 | 186 |
Ameren Illinois Company | Natural Gas | Other current assets | |||
Derivative [Line Items] | |||
Derivative assets | 1 | 1 | |
Ameren Illinois Company | Natural Gas | MTM derivative liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 32 | 31 | |
Ameren Illinois Company | Natural Gas | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 18 | 13 | |
Ameren Illinois Company | Power | MTM derivative liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | 13 | 11 | |
Ameren Illinois Company | Power | Other deferred credits and liabilities | |||
Derivative [Line Items] | |||
Derivative liabilities | $ 157 | $ 131 | |
[1] | Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net gains on all derivative instruments is deferred as a regulatory liability. | ||
[2] | Because all contracts qualifying for hedge accounting receive regulatory deferral, the cumulative amount of pretax net losses on all derivative instruments is deferred as a regulatory asset. |
Derivative Financial Instrume75
Derivative Financial Instruments Derivative Financial Instruments (Offsetting Derivative Assets and Liabilities) (Details) - Commodity Contract - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | $ 18 | [1] | $ 19 | [2] | |
Derivative Instruments | 1 | 5 | |||
Net Amount | 17 | 14 | |||
Gross Amounts Recognized in the Balance Sheet | 264 | [1] | 232 | [2] | |
Derivative Instruments | 1 | 5 | |||
Cash Collateral Received/Posted | [3] | 11 | 5 | ||
Net Amount | 252 | 222 | |||
Union Electric Company | |||||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | 17 | [1] | 18 | [2] | |
Derivative Instruments | 1 | 5 | |||
Net Amount | 16 | 13 | |||
Gross Amounts Recognized in the Balance Sheet | 44 | [1] | 46 | [2] | |
Derivative Instruments | 1 | 5 | |||
Cash Collateral Received/Posted | [3] | 8 | 5 | ||
Net Amount | 35 | 36 | |||
Ameren Illinois Company | |||||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | 1 | 1 | |||
Net Amount | 1 | 1 | |||
Gross Amounts Recognized in the Balance Sheet | 220 | [1] | 186 | [2] | |
Cash Collateral Received/Posted | [3] | 3 | |||
Net Amount | $ 217 | $ 186 | |||
[1] | The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[2] | The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[3] | Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. |
Derivative Financial Instrume76
Derivative Financial Instruments (Derivative Instruments With Credit Risk-Related Contingent Features) (Details) $ in Millions | Dec. 31, 2015USD ($) | |
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | $ 165 | [1] |
Cash Collateral Posted | 12 | |
Potential Aggregate Amount of Additional Collateral Required | 143 | [2] |
Union Electric Company | ||
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | 87 | [1] |
Cash Collateral Posted | 9 | |
Potential Aggregate Amount of Additional Collateral Required | 72 | [2] |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | 78 | [1] |
Cash Collateral Posted | 3 | |
Potential Aggregate Amount of Additional Collateral Required | $ 71 | [2] |
[1] | Before consideration of master netting arrangements or similar agreements and including NPNS and other accrual contract exposures. | |
[2] | As collateral requirements with certain counterparties are based on master netting arrangements or similar agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such arrangements. |
Fair Value Measurements (Schedu
Fair Value Measurements (Schedule of Valuation Process and Unobservable Inputs) (Details) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2015USD ($)$ / MMBTU$ / credit$ / MW$ / MWh$ / lb | Dec. 31, 2014USD ($)$ / MMBTU$ / credit$ / MW$ / MWh$ / lb | ||||
Discounted Cash Flow | Minimum | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [1],[2] | 5.00% | |||
Counterparty credit risk | [3],[4] | 0.43% | |||
Discounted Cash Flow | Minimum | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 0.40% | 0.43% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Nodal basis | [2] | (0.10) | (0.40) | ||
Discounted Cash Flow | Minimum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 0.86% | 0.26% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Average bid/ask consensus peak and off-peak pricing | [5] | 22 | 27 | ||
Estimated auction price for FTRs | $ / MW | [2] | (270) | (1,833) | ||
Nodal basis | (10) | [5] | (6) | [2] | |
Discounted Cash Flow | Minimum | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Credit risk | [3],[4] | 0.40% | |||
Average bid/ask consensus pricing | $ / lb | [2] | 35 | 35 | ||
Discounted Cash Flow | Maximum | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [1],[2] | 5.00% | |||
Counterparty credit risk | [3],[4] | 0.43% | |||
Discounted Cash Flow | Maximum | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 12.00% | 13.00% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Nodal basis | [2] | 0 | 0.10 | ||
Discounted Cash Flow | Maximum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 0.86% | 0.26% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Average bid/ask consensus peak and off-peak pricing | [5] | 39 | 50 | ||
Estimated auction price for FTRs | $ / MW | [2] | 2,057 | 2,743 | ||
Nodal basis | (1) | [5] | 0 | [2] | |
Discounted Cash Flow | Maximum | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Credit risk | [3],[4] | 0.40% | |||
Average bid/ask consensus pricing | $ / lb | [2] | 42 | 40 | ||
Discounted Cash Flow | Weighted Average | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [1],[2] | 5.00% | |||
Counterparty credit risk | [3],[4] | 0.43% | |||
Discounted Cash Flow | Weighted Average | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 7.00% | 3.00% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Nodal basis | [2] | (0.10) | (0.20) | ||
Discounted Cash Flow | Weighted Average | Power | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 0.86% | 0.26% | ||
Credit risk | [3],[4] | 0.40% | 0.43% | ||
Average bid/ask consensus peak and off-peak pricing | [5] | 29 | 32 | ||
Estimated auction price for FTRs | $ / MW | [2] | 211 | 171 | ||
Nodal basis | (3) | [5] | (2) | [2] | |
Discounted Cash Flow | Weighted Average | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Credit risk | [3],[4] | 0.40% | |||
Average bid/ask consensus pricing | $ / lb | [2] | 37 | 36 | ||
Option Model | Minimum | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [4] | 3.00% | |||
Option Model | Minimum | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 35.00% | [2] | 31.00% | [4] | |
Nodal basis | (0.30) | [4] | (0.40) | [2] | |
Option Model | Minimum | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [2] | 20.00% | |||
Option Model | Maximum | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [4] | 39.00% | |||
Option Model | Maximum | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 55.00% | [2] | 144.00% | [4] | |
Nodal basis | 0 | [4] | 0 | [2] | |
Option Model | Maximum | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [2] | 20.00% | |||
Option Model | Weighted Average | Fuel Oils | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [4] | 32.00% | |||
Option Model | Weighted Average | Natural Gas | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 45.00% | [2] | 63.00% | [4] | |
Nodal basis | (0.20) | [4] | (0.20) | [2] | |
Option Model | Weighted Average | Uranium | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [2] | 20.00% | |||
Fundamental Energy Production Model | Minimum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [2],[6] | 3.00% | 0.00% | ||
Estimated future gas prices | $ / MMBTU | [2] | 3 | 4 | ||
Fundamental Energy Production Model | Maximum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [2],[6] | 3.00% | 1.00% | ||
Estimated future gas prices | $ / MMBTU | [2] | 4 | 5 | ||
Fundamental Energy Production Model | Weighted Average | Power | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [2],[6] | 3.00% | 1.00% | ||
Estimated future gas prices | $ / MMBTU | [2] | 4 | 4 | ||
Contract Price Allocation | Minimum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | [2] | 5 | 5 | ||
Contract Price Allocation | Maximum | Power | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | [2] | 7 | 7 | ||
Contract Price Allocation | Weighted Average | Power | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | [2] | 6 | 6 | ||
Derivative liabilities | Fuel Oils | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ | [7] | $ (8) | |||
Derivative liabilities | Natural Gas | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ | [7] | $ (1) | (2) | ||
Derivative liabilities | Power | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ | [7],[8] | (170) | (144) | ||
Derivative liabilities | Uranium | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ | [7] | (1) | $ (2) | ||
Derivative assets | Natural Gas | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ | [7] | 1 | |||
Derivative assets | Power | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ | [7],[8] | $ 16 | |||
[1] | Escalation rate applies to fuel oil prices 2017 and beyond. | ||||
[2] | Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. | ||||
[3] | Counterparty credit risk is applied only to counterparties with derivative asset balances. Ameren Missouri and Ameren Illinois credit risk is applied only to counterparties with derivative liability balances. | ||||
[4] | Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. | ||||
[5] | The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes because of their opposing positions. | ||||
[6] | Escalation rate applies to power prices 2026 and beyond. | ||||
[7] | The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[8] | Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2019. Valuations beyond 2019 use fundamentally modeled pricing by month for peak and off-peak demand |
Fair Value Measurements (Sche78
Fair Value Measurements (Schedule Of Fair Value Hierarchy Of Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | $ 557 | [1] | $ 547 | [2] | |
Assets | 575 | [3] | 566 | [4] | |
Excluded receivables, payables, and accrued income, net | (1) | 2 | |||
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 368 | 365 | |||
Assets | 368 | [3] | 365 | [4] | |
Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 189 | 182 | |||
Assets | 190 | [3] | 187 | [4] | |
Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Assets | 17 | [3] | 14 | [4] | |
Cash And Cash Equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 4 | 1 | |||
Cash And Cash Equivalents | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 4 | 1 | |||
Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 18 | [3] | 19 | [4] | |
Derivative liabilities | 264 | [3] | 232 | [4] | |
Commodity Contract | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 30 | [3] | 22 | [4] | |
Commodity Contract | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 5 | [4] | |
Derivative liabilities | 62 | [3] | 54 | [4] | |
Commodity Contract | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 17 | [3] | 14 | [4] | |
Derivative liabilities | 172 | [3] | 156 | [4] | |
Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 2 | |||
Derivative liabilities | 29 | [3] | 29 | [4] | |
Commodity Contract | Fuel Oils | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | $ 29 | [3] | 21 | [4] | |
Commodity Contract | Fuel Oils | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [3] | 2 | |||
Derivative liabilities | [3] | 8 | [4] | ||
Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | $ 2 | [3] | 2 | [4] | |
Derivative liabilities | 64 | [3] | 56 | [4] | |
Commodity Contract | Natural Gas | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 1 | [4] | |
Commodity Contract | Natural Gas | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 1 | [4] | |
Derivative liabilities | 62 | [3] | 53 | [4] | |
Commodity Contract | Natural Gas | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [3] | 1 | 1 | ||
Derivative liabilities | 1 | [3] | 2 | [4] | |
Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 16 | [3] | 15 | [4] | |
Derivative liabilities | 170 | [3] | 145 | [4] | |
Commodity Contract | Power | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 4 | |||
Derivative liabilities | [4] | 1 | |||
Commodity Contract | Power | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [3] | 16 | 11 | ||
Derivative liabilities | 170 | [3] | 144 | [4] | |
Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 2 | [4] | |
Commodity Contract | Uranium | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 2 | [4] | |
Equity Securities | U.S. Large Capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 364 | 364 | |||
Equity Securities | U.S. Large Capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 364 | 364 | |||
Debt Securities | Corporate Bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 58 | 63 | |||
Debt Securities | Corporate Bonds | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 58 | 63 | |||
Debt Securities | U.S. treasury and agency securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 109 | 102 | |||
Debt Securities | U.S. treasury and agency securities | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 109 | 102 | |||
Debt Securities | Other debt securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Debt Securities | Other debt securities | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 557 | [1] | 547 | [2] | |
Assets | 574 | [3] | 565 | [4] | |
Union Electric Company | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 368 | 365 | |||
Assets | 368 | [3] | 365 | [4] | |
Union Electric Company | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 189 | 182 | |||
Assets | 189 | [3] | 187 | [4] | |
Union Electric Company | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Assets | 17 | [3] | 13 | [4] | |
Union Electric Company | Cash And Cash Equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 4 | 1 | |||
Union Electric Company | Cash And Cash Equivalents | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 4 | 1 | |||
Union Electric Company | Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 17 | [3] | 18 | [4] | |
Derivative liabilities | 44 | [3] | 46 | [4] | |
Union Electric Company | Commodity Contract | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 29 | [3] | 22 | [4] | |
Union Electric Company | Commodity Contract | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 5 | |||
Derivative liabilities | 13 | [3] | 11 | [4] | |
Union Electric Company | Commodity Contract | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 17 | [3] | 13 | [4] | |
Derivative liabilities | 2 | [3] | 13 | [4] | |
Union Electric Company | Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 2 | |||
Derivative liabilities | 29 | [3] | 29 | [4] | |
Union Electric Company | Commodity Contract | Fuel Oils | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 29 | [3] | 21 | [4] | |
Union Electric Company | Commodity Contract | Fuel Oils | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 2 | |||
Derivative liabilities | [4] | 8 | |||
Union Electric Company | Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 1 | [4] | |
Derivative liabilities | 14 | [3] | 12 | [4] | |
Union Electric Company | Commodity Contract | Natural Gas | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | [4] | 1 | |||
Union Electric Company | Commodity Contract | Natural Gas | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 1 | |||
Derivative liabilities | 13 | [3] | 10 | [4] | |
Union Electric Company | Commodity Contract | Natural Gas | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [3] | 1 | |||
Derivative liabilities | 1 | [3] | 1 | [4] | |
Union Electric Company | Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 16 | [3] | 15 | [4] | |
Derivative liabilities | 0 | [3] | 3 | [4] | |
Union Electric Company | Commodity Contract | Power | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 4 | |||
Derivative liabilities | [4] | 1 | |||
Union Electric Company | Commodity Contract | Power | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 16 | [3] | 11 | [4] | |
Derivative liabilities | [4] | 2 | |||
Union Electric Company | Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 2 | [4] | |
Union Electric Company | Commodity Contract | Uranium | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 2 | [4] | |
Union Electric Company | Equity Securities | U.S. Large Capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 364 | 364 | |||
Union Electric Company | Equity Securities | U.S. Large Capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 364 | 364 | |||
Union Electric Company | Debt Securities | Corporate Bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 58 | 63 | |||
Union Electric Company | Debt Securities | Corporate Bonds | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 58 | 63 | |||
Union Electric Company | Debt Securities | U.S. treasury and agency securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 109 | 102 | |||
Union Electric Company | Debt Securities | U.S. treasury and agency securities | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 109 | 102 | |||
Union Electric Company | Debt Securities | Other debt securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Union Electric Company | Debt Securities | Other debt securities | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Ameren Illinois Company | Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | 1 | |||
Derivative liabilities | 220 | [3] | 186 | [4] | |
Ameren Illinois Company | Commodity Contract | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 1 | [3] | 0 | [4] | |
Ameren Illinois Company | Commodity Contract | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 49 | [3] | 43 | [4] | |
Ameren Illinois Company | Commodity Contract | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 170 | [3] | 143 | [4] | |
Ameren Illinois Company | Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 1 | [4] | |
Derivative liabilities | 50 | [3] | 44 | [4] | |
Ameren Illinois Company | Commodity Contract | Natural Gas | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | [3] | 1 | |||
Ameren Illinois Company | Commodity Contract | Natural Gas | Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [3] | 1 | |||
Derivative liabilities | 49 | [3] | 43 | [4] | |
Ameren Illinois Company | Commodity Contract | Natural Gas | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 1 | |||
Derivative liabilities | [4] | 1 | |||
Ameren Illinois Company | Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 170 | [3] | 142 | [4] | |
Ameren Illinois Company | Commodity Contract | Power | Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | $ 170 | [3] | $ 142 | [4] | |
[1] | Balance excludes $(1) million of receivables, payables, and accrued income, net. | ||||
[2] | Balance excludes $2 million of receivables, payables, and accrued income, net. | ||||
[3] | The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[4] | The derivative asset and liability balances are presented net of counterparty credit considerations. |
Fair Value Measurements (Sche79
Fair Value Measurements (Schedule Of Changes In The Fair Value Of Financial Assets And Liabilities Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2015 | Dec. 31, 2014 | |
Fuel Oils | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | $ (6) | $ 5 |
Included in regulatory assets/liabilities | (1) | (9) |
Settlements | 5 | (2) |
Transfers out of Level 3 | 2 | |
Ending balance | 0 | (6) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | (6) |
Natural Gas | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (1) | 0 |
Included in regulatory assets/liabilities | 1 | 1 |
Purchases | (2) | |
Sales | (1) | |
Settlements | 0 | 1 |
Ending balance | 0 | (1) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | 2 |
Power | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (133) | (89) |
Included in regulatory assets/liabilities | (39) | (53) |
Purchases | 29 | 34 |
Sales | (1) | |
Settlements | (10) | (24) |
Transfers out of Level 3 | (1) | |
Ending balance | (154) | (133) |
Change in unrealized gains (losses) related to assets/liabilities still held | (39) | (43) |
Uranium | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (2) | (6) |
Included in regulatory assets/liabilities | (1) | (1) |
Settlements | 2 | 5 |
Ending balance | (1) | (2) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | (1) |
Union Electric Company | Fuel Oils | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (6) | 5 |
Included in regulatory assets/liabilities | (1) | (9) |
Settlements | 5 | (2) |
Transfers out of Level 3 | 2 | |
Ending balance | 0 | (6) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | (6) |
Union Electric Company | Natural Gas | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (1) | 0 |
Sales | (1) | |
Settlements | 1 | |
Ending balance | 0 | (1) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | 0 |
Union Electric Company | Power | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | 9 | 19 |
Included in regulatory assets/liabilities | 2 | (14) |
Purchases | 29 | 34 |
Sales | (1) | |
Settlements | (23) | (29) |
Transfers out of Level 3 | (1) | |
Ending balance | 16 | 9 |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | 0 |
Union Electric Company | Uranium | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (2) | (6) |
Included in regulatory assets/liabilities | (1) | (1) |
Settlements | 2 | 5 |
Ending balance | (1) | (2) |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | (1) |
Ameren Illinois Company | Natural Gas | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | 0 | 0 |
Included in regulatory assets/liabilities | 1 | 1 |
Purchases | (2) | |
Settlements | (1) | 1 |
Ending balance | 0 | 0 |
Change in unrealized gains (losses) related to assets/liabilities still held | 0 | 2 |
Ameren Illinois Company | Power | ||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||
Beginning balance | (142) | (108) |
Included in regulatory assets/liabilities | (41) | (39) |
Settlements | 13 | 5 |
Ending balance | (170) | (142) |
Change in unrealized gains (losses) related to assets/liabilities still held | $ (39) | $ (43) |
Fair Value Measurements (Sche80
Fair Value Measurements (Schedule Of Carrying Amounts And Estimated Fair Values Of Long-Term Debt And Preferred Stock) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Carrying Amount | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term Debt and Capital Lease Obligations | [1] | $ 7,275 | $ 6,205 |
Preferred stock | [1] | 142 | 142 |
Fair Value | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt and capital lease obligations (including current portion) | [1] | 7,814 | 7,135 |
Preferred stock | [1] | 125 | 122 |
Union Electric Company | Carrying Amount | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term Debt and Capital Lease Obligations | 4,110 | 3,981 | |
Preferred stock | 80 | 80 | |
Union Electric Company | Fair Value | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt and capital lease obligations (including current portion) | 4,449 | 4,518 | |
Preferred stock | 75 | 73 | |
Ameren Illinois Company | Carrying Amount | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term Debt and Capital Lease Obligations | 2,471 | 2,224 | |
Preferred stock | 62 | 62 | |
Ameren Illinois Company | Fair Value | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt and capital lease obligations (including current portion) | 2,665 | 2,517 | |
Preferred stock | $ 50 | $ 49 | |
[1] | Preferred stock is recorded in "Noncontrolling Interests" on the consolidated balance sheet.(b)Carrying amounts reflect the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs. See Note 1 – Summary of Significant Accounting Policies |
Nuclear Decommissioning Trust81
Nuclear Decommissioning Trust Fund Investments (Proceeds From The Sale Of Investments And Related Gross Realized Gains And Losses In Nuclear Decommissioning Trust Fund) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |||
Sales and maturities of securities - nuclear decommissioning trust fund | $ 349 | $ 391 | $ 196 |
Gross realized gains | 8 | 7 | 7 |
Gross realized losses | $ 2 | 2 | 5 |
Minimum | Nuclear Decommissioning Trust Fund | |||
Nuclear Decommissioning Trust Fund Investments [Line Items] | |||
Trust fund investments, target allocation percentage | 60.00% | ||
Maximum | Nuclear Decommissioning Trust Fund | |||
Nuclear Decommissioning Trust Fund Investments [Line Items] | |||
Trust fund investments, target allocation percentage | 70.00% | ||
Union Electric Company | |||
Nuclear Decommissioning Trust Fund Investments [Line Items] | |||
Sales and maturities of securities - nuclear decommissioning trust fund | $ 349 | $ 391 | $ 196 |
Nuclear Decommissioning Trust82
Nuclear Decommissioning Trust Fund Investments (Fair Values Of Investments In Debt And Equity Securities In Nuclear Decommissioning Trust Fund) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 |
Nuclear Decommissioning Trust Fund Investments [Line Items] | ||
Cost | $ 341 | $ 316 |
Available-for-sale Debt Securities, Accumulated Gross Unrealized Gain, before Tax | 226 | 237 |
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax | 11 | 4 |
Fair Value | 556 | 549 |
Debt Securities | ||
Nuclear Decommissioning Trust Fund Investments [Line Items] | ||
Cost | 191 | 175 |
Available-for-sale Debt Securities, Accumulated Gross Unrealized Gain, before Tax | 2 | 7 |
Available-for-sale Debt Securities, Accumulated Gross Unrealized Loss, before Tax | 4 | 0 |
Fair Value | 189 | 182 |
Equity Securities | ||
Nuclear Decommissioning Trust Fund Investments [Line Items] | ||
Cost | 147 | 138 |
Available-for-sale Debt Securities, Accumulated Gross Unrealized Gain, before Tax | 224 | 230 |
Available-for-sale Equity Securities, Accumulated Gross Unrealized Loss, before Tax | 7 | 4 |
Fair Value | 364 | 364 |
Cash | ||
Nuclear Decommissioning Trust Fund Investments [Line Items] | ||
Cost | 4 | 1 |
Fair Value | 4 | 1 |
Other Debt And Equity Securities | ||
Nuclear Decommissioning Trust Fund Investments [Line Items] | ||
Cost | (1) | 2 |
Fair Value | $ (1) | $ 2 |
Nuclear Decommissioning Trust83
Nuclear Decommissioning Trust Fund Investments (Costs And Fair Values Of Investments In Debt Securities In Nuclear Decommissioning Trust Fund According To Contractual Maturities) (Details) $ in Millions | Dec. 31, 2015USD ($) |
Investments, Debt and Equity Securities [Abstract] | |
Cost, Less than 5 years | $ 106 |
Cost, 5 years to 10 years | 42 |
Cost, Due after 10 years | 43 |
Cost, Total | 191 |
Fair Value, Less than 5 years | 105 |
Fair Value, 5 years to 10 years | 41 |
Fair Value, Due after 10 years | 43 |
Fair Value, Total | $ 189 |
Nuclear Decommissioning Trust84
Nuclear Decommissioning Trust Fund Investments (Fair Value And The Gross Unrealized Losses Of The Available-For-Sale Securities Held In Nuclear Decommissioning Trust Fund) (Details) $ in Millions | Dec. 31, 2015USD ($) |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |
Less than 12 months, fair value | $ 152 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss | 6 |
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss | 5 |
12 months or greater, fair value | 8 |
Total, fair value | 160 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss | 11 |
Debt Securities | |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |
Less than 12 months, fair value | 136 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss | 3 |
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss | 1 |
12 months or greater, fair value | 4 |
Total, fair value | 140 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss | 4 |
Equity Securities | |
Nuclear Decommissioning Trust Fund Investments [Line Items] | |
Less than 12 months, fair value | 16 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss | 3 |
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss | 4 |
12 months or greater, fair value | 4 |
Total, fair value | 20 |
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss | $ 7 |
Callaway Energy Center (Details
Callaway Energy Center (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2015USD ($)mill | |
Loss Contingencies [Line Items] | |
Nwf Fee Number Of Mills | mill | 1 |
Nuclear Plant | |
Loss Contingencies [Line Items] | |
Annual decommissioning costs included in costs of service | $ | $ 7 |
Retirement Benefits (Narrative)
Retirement Benefits (Narrative) (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015USD ($)bondpartnership | Dec. 31, 2014USD ($) | ||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Funded Status of Plan | [1] | $ 567 | $ 710 |
Defined Benefit Plan Assumptions Used Calculating Benefit Obligation, Change in Discount Rate | 0.50% | ||
Number of high-quality corporate bonds | bond | 700 | ||
Defined benefit plan, estimated future employer contributions during the next five years | $ 280 | ||
Amortization basis, straight line, in years | 10 years | ||
Pension Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Funded Status of Plan | [1] | $ (544) | (616) |
Assumptions used calculating net periodic benefit cost, expected long-term return on assets in future years | 7.00% | ||
Postretirement Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Funded Status of Plan | [1] | $ (23) | $ (94) |
Assumptions used calculating net periodic benefit cost, expected long-term return on assets in future years | 7.00% | ||
Minimum | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined benefit plan, estimated future employer contributions during the next five years | $ 40 | ||
Maximum | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined benefit plan, estimated future employer contributions during the next five years | $ 70 | ||
Private equity | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Number of limited partnerships in private equity funds | partnership | 8 | ||
Minimum invested capital within limited partnership investments | $ 1 | ||
Maximum invested capital within limited partnership investments | $ 4 | ||
Union Electric Company | Pension Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Future funding requirement, percentage | 40.00% | ||
Ameren Illinois Company | Pension Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Future funding requirement, percentage | 50.00% | ||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Retirement Benefits (Summary Of
Retirement Benefits (Summary Of Benefit Liability Recorded) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plan Disclosure [Line Items] | |||
Benefit liability recorded on the balance sheet | [1] | $ 567 | $ 710 |
Union Electric Company | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Benefit liability recorded on the balance sheet | 236 | 277 | |
Ameren Illinois Company | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Benefit liability recorded on the balance sheet | $ 219 | $ 278 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Retirement Benefits (Funded Sta
Retirement Benefits (Funded Status Of Benefit Plans And Amounts Included In Regulatory Assets And OCI) (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||||
Change in plan assets: | ||||||
Funded status – deficiency | [1] | $ (567) | $ (710) | |||
Amounts recognized in the balance sheet consist of: | ||||||
Noncurrent liability | 580 | 705 | ||||
Net liability recognized | [2] | 567 | 710 | |||
Pension Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Accumulated benefit obligation at end of year | [1] | 3,995 | 4,176 | |||
Change in benefit obligation: | ||||||
Net benefit obligation at beginning of year | [1] | 4,410 | 3,900 | |||
Service cost | [3] | 92 | [1] | 79 | [1] | $ 91 |
Interest cost | [3] | 174 | [1] | 183 | [1] | 163 |
Actuarial (gain) loss | [1] | (256) | 462 | |||
Settlement | [1] | (2) | ||||
Benefits paid | [1] | (221) | (214) | |||
Net benefit obligation at end of year | [1] | 4,197 | 4,410 | 3,900 | ||
Change in plan assets: | ||||||
Fair value of plan assets at beginning of year | [1] | 3,794 | 3,461 | |||
Actual return on plan assets | [1] | (29) | 448 | |||
Employer contributions | [2] | 111 | [1] | 99 | [1] | 156 |
Settlement | [1] | (2) | ||||
Benefits paid | [1] | (221) | (214) | |||
Fair value of plan assets at end of year | [1] | 3,653 | 3,794 | 3,461 | ||
Funded status – deficiency | [1] | 544 | 616 | |||
Accrued benefit cost at December 31 | [1] | 544 | 616 | |||
Amounts recognized in the balance sheet consist of: | ||||||
Current liability(d) | [1],[4] | 3 | 3 | |||
Noncurrent liability | [1] | 541 | 613 | |||
Net liability recognized | [1] | 544 | 616 | |||
Amounts recognized in regulatory assets consist of: | ||||||
Net actuarial (gain) loss | [1] | 395 | 452 | |||
Prior service cost (credit) | [1] | (5) | (6) | |||
Amounts (pretax) recognized in accumulated OCI consist of: | ||||||
Net actuarial (gain) loss | [1] | 17 | 29 | |||
Prior service cost (credit) | [1] | 0 | ||||
Total | [1] | 407 | 475 | |||
Postretirement Benefits | ||||||
Change in benefit obligation: | ||||||
Net benefit obligation at beginning of year | [1] | 1,203 | 1,096 | |||
Service cost | [3] | 24 | [1] | 19 | [1] | 22 |
Interest cost | [3] | 48 | [1] | 50 | [1] | 46 |
Participant contributions | [1] | 8 | 16 | |||
Actuarial (gain) loss | [1] | (133) | 84 | |||
Benefits paid | [1] | (56) | (65) | |||
Federal subsidy on benefits paid | [1] | 0 | 3 | |||
Net benefit obligation at end of year | [1] | 1,094 | 1,203 | 1,096 | ||
Change in plan assets: | ||||||
Fair value of plan assets at beginning of year | [1] | 1,109 | 1,074 | |||
Actual return on plan assets | [1] | (8) | 75 | |||
Employer contributions | [2] | 18 | [1] | 6 | [1] | 25 |
Federal subsidy on benefits paid | [1] | 0 | 3 | |||
Participant contributions | [1] | 8 | 16 | |||
Benefits paid | [1] | (56) | (65) | |||
Fair value of plan assets at end of year | [1] | 1,071 | 1,109 | $ 1,074 | ||
Funded status – deficiency | [1] | 23 | 94 | |||
Accrued benefit cost at December 31 | [1] | 23 | 94 | |||
Amounts recognized in the balance sheet consist of: | ||||||
Noncurrent asset | [1],[5] | (18) | ||||
Current liability(d) | [1],[4] | 2 | 2 | |||
Noncurrent liability | [1] | 39 | 92 | |||
Net liability recognized | [1] | 23 | 94 | |||
Amounts recognized in regulatory assets consist of: | ||||||
Net actuarial (gain) loss | [1] | (82) | (7) | |||
Prior service cost (credit) | [1] | (11) | (16) | |||
Amounts (pretax) recognized in accumulated OCI consist of: | ||||||
Net actuarial (gain) loss | [1] | (3) | (5) | |||
Prior service cost (credit) | [1] | 0 | (1) | |||
Total | [1] | $ (96) | $ (29) | |||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. | |||||
[2] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. | |||||
[3] | Includes amounts for Ameren registrant and nonregistrant subsidiaries | |||||
[4] | Included in "Other current liabilities" on Ameren's consolidated balance sheet. | |||||
[5] | Included in "Other assets" on Ameren's consolidated balance sheet. |
Retirement Benefits (Assumption
Retirement Benefits (Assumptions Used To Determine Benefit Obligations) (Details) | 12 Months Ended | |
Dec. 31, 2015 | Dec. 31, 2014 | |
Pension Benefits | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Discount rate at measurement date | 4.50% | 4.00% |
Increase in future compensation | 3.50% | 3.50% |
Postretirement Benefits | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Discount rate at measurement date | 4.50% | 4.00% |
Increase in future compensation | 3.50% | 3.50% |
Medical cost trend rate (initial) | 5.00% | 5.00% |
Medical cost trend rate (ultimate) | 5.00% | 5.00% |
Retirement Benefits (Cash Contr
Retirement Benefits (Cash Contributions Made To Benefit Plans) (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||||
Pension Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | [2] | $ 111 | [1] | $ 99 | [1] | $ 156 |
Postretirement Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | [2] | 18 | [1] | 6 | [1] | 25 |
Union Electric Company | Pension Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | 47 | 41 | 60 | |||
Union Electric Company | Postretirement Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | 8 | 3 | 10 | |||
Ameren Illinois Company | Pension Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | 45 | 39 | 50 | |||
Ameren Illinois Company | Postretirement Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | 8 | 2 | 11 | |||
Other | Pension Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | 19 | 19 | 46 | |||
Other | Postretirement Benefits | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||
Cash contributions to benefit plans | $ 2 | $ 1 | $ 4 | |||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. | |||||
[2] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Retirement Benefits (Target All
Retirement Benefits (Target Allocation Of The Plans' Asset Categories) (Details) | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | ||
Pension Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Actual Plan Asset Allocations | 100.00% | 100.00% | |
Pension Benefits | Cash And Cash Equivalents | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 0.00% | ||
Maximum Target Allocation | 5.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 1.00% | 2.00% | |
Pension Benefits | Equity Securities | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 51.00% | ||
Maximum Target Allocation | 61.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 54.00% | 53.00% | |
Pension Benefits | U.S. large capitalization | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 29.00% | ||
Maximum Target Allocation | 39.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 34.00% | 34.00% | |
Pension Benefits | U.S. small and mid-capitalization | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 3.00% | ||
Maximum Target Allocation | 13.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 7.00% | 7.00% | |
Pension Benefits | International and emerging markets | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 9.00% | ||
Maximum Target Allocation | 19.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 13.00% | 12.00% | |
Pension Benefits | Debt Securities | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 35.00% | ||
Maximum Target Allocation | 45.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 40.00% | 41.00% | |
Pension Benefits | Real estate | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 0.00% | ||
Maximum Target Allocation | 9.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 5.00% | 4.00% | |
Pension Benefits | Private equity | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 0.00% | ||
Maximum Target Allocation | 5.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | [1] | 1.00% | 1.00% |
Postretirement Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Actual Plan Asset Allocations | 100.00% | 100.00% | |
Postretirement Benefits | Cash And Cash Equivalents | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 0.00% | ||
Maximum Target Allocation | 7.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 4.00% | 4.00% | |
Postretirement Benefits | Equity Securities | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 55.00% | ||
Maximum Target Allocation | 65.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 59.00% | 60.00% | |
Postretirement Benefits | U.S. large capitalization | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 34.00% | ||
Maximum Target Allocation | 44.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 39.00% | 40.00% | |
Postretirement Benefits | U.S. small and mid-capitalization | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 2.00% | ||
Maximum Target Allocation | 12.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 7.00% | 7.00% | |
Postretirement Benefits | International | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 9.00% | ||
Maximum Target Allocation | 19.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 13.00% | 13.00% | |
Postretirement Benefits | Debt Securities | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Minimum Target Allocation | 33.00% | ||
Maximum Target Allocation | 43.00% | ||
Defined Benefit Plan, Actual Plan Asset Allocations | 37.00% | 36.00% | |
[1] | (a)Less than 1% of plan assets. |
Retirement Benefits (Fair Value
Retirement Benefits (Fair Value Of Plan Assets Utilizing Fair Value Hierarchy) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Real estate | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | $ 168 | $ 147 | $ 131 | |
Private equity | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 8 | 13 | 15 | |
Pension Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [1] | 3,653 | 3,794 | 3,461 |
Pension Benefits | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 396 | 411 | ||
Pension Benefits | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 3,176 | 3,327 | ||
Pension Benefits | Significant Other Unobservable Inputs (Level 3) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 176 | 160 | ||
Pension Benefits | Cash And Cash Equivalents | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 20 | 38 | ||
Pension Benefits | Cash And Cash Equivalents | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 0 | 0 | ||
Pension Benefits | Cash And Cash Equivalents | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 20 | 38 | ||
Pension Benefits | U.S. large capitalization | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 1,296 | 1,331 | ||
Pension Benefits | U.S. large capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 0 | 0 | ||
Pension Benefits | U.S. large capitalization | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 1,296 | 1,331 | ||
Pension Benefits | U.S. small and mid-capitalization | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 268 | 270 | ||
Pension Benefits | U.S. small and mid-capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 268 | 270 | ||
Pension Benefits | U.S. small and mid-capitalization | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 0 | 0 | ||
Pension Benefits | International and emerging markets | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 491 | 494 | ||
Pension Benefits | International and emerging markets | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 122 | 134 | ||
Pension Benefits | International and emerging markets | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 369 | 360 | ||
Pension Benefits | Corporate Bonds | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 631 | 1,026 | ||
Pension Benefits | Corporate Bonds | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 631 | 1,026 | ||
Pension Benefits | Municipal Bonds | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 104 | 175 | ||
Pension Benefits | Municipal Bonds | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 104 | 175 | ||
Pension Benefits | U.S. treasury and agency securities | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 757 | 372 | ||
Pension Benefits | U.S. treasury and agency securities | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 6 | 6 | ||
Pension Benefits | U.S. treasury and agency securities | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 751 | 366 | ||
Pension Benefits | Other | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 5 | 31 | ||
Pension Benefits | Other | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 5 | 31 | ||
Pension Benefits | Real estate | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 168 | 147 | ||
Pension Benefits | Real estate | Significant Other Unobservable Inputs (Level 3) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 168 | 147 | ||
Pension Benefits | Private equity | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 8 | 13 | ||
Pension Benefits | Private equity | Significant Other Unobservable Inputs (Level 3) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 8 | 13 | ||
Pension Benefits | Derivative assets | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 1 | |||
Pension Benefits | Derivative assets | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 1 | |||
Pension Benefits | Medical benefit assets | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [2] | (123) | (125) | |
Pension Benefits | Net receivables | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [3] | 28 | 21 | |
Pension Benefits | Includes Medical Benefit Component Under Section401 H And Excludes Receivables Related To Pending Security Sales [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 3,748 | 3,898 | ||
Pension Benefits | Excludes Medical Benefit Component Under Section401 H And Includes Receivables Related To Pending Security Sales [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 3,653 | 3,794 | ||
Postretirement Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [1] | 1,071 | 1,109 | $ 1,074 |
Postretirement Benefits | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 431 | 487 | ||
Postretirement Benefits | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 545 | 551 | ||
Postretirement Benefits | Cash And Cash Equivalents | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 61 | 89 | ||
Postretirement Benefits | Cash And Cash Equivalents | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 61 | 89 | ||
Postretirement Benefits | Cash And Cash Equivalents | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 0 | 0 | ||
Postretirement Benefits | U.S. large capitalization | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 370 | 392 | ||
Postretirement Benefits | U.S. large capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 272 | 291 | ||
Postretirement Benefits | U.S. large capitalization | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 98 | 101 | ||
Postretirement Benefits | U.S. small and mid-capitalization | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 65 | 70 | ||
Postretirement Benefits | U.S. small and mid-capitalization | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 65 | 70 | ||
Postretirement Benefits | International | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 126 | 131 | ||
Postretirement Benefits | International | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 33 | 37 | ||
Postretirement Benefits | International | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 93 | 94 | ||
Postretirement Benefits | Other Equity | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 7 | 7 | ||
Postretirement Benefits | Other Equity | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 7 | 7 | ||
Postretirement Benefits | Corporate Bonds | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 138 | 105 | ||
Postretirement Benefits | Corporate Bonds | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 138 | 105 | ||
Postretirement Benefits | Municipal Bonds | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 114 | 111 | ||
Postretirement Benefits | Municipal Bonds | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 114 | 111 | ||
Postretirement Benefits | U.S. treasury and agency securities | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 55 | 89 | ||
Postretirement Benefits | U.S. treasury and agency securities | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 55 | 89 | ||
Postretirement Benefits | Other | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 40 | 44 | ||
Postretirement Benefits | Other | Significant Other Observable Inputs (Level 2) | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 40 | 44 | ||
Postretirement Benefits | Medical benefit assets | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [2] | 123 | 125 | |
Postretirement Benefits | Net payables | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | [4] | (28) | (54) | |
Postretirement Benefits | Excludes Medical Benefit Component Under Section401 H And Excludes Payables Related To Pending Security Sales [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | 976 | 1,038 | ||
Postretirement Benefits | Includes Medical Benefit Component Under Section401 H And Excludes Payables Related To Pending Security Sales [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Fair value of plan assets | $ 1,071 | $ 1,109 | ||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. | |||
[2] | Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. | |||
[3] | Receivables related to pending security sales, offset by payables related to pending security purchases. | |||
[4] | Payables related to pending security purchases, offset by interest receivables and receivables related to pending security sales. |
Retirement Benefits (Changes In
Retirement Benefits (Changes In The Fair Value Of Plan Assets Classified As Level 3) (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2015 | Dec. 31, 2014 | |
Real estate | ||
Change in plan assets: | ||
Fair value of plan assets at beginning of year | $ 147 | $ 131 |
Actual Return on Plan Assets Related to Assets Still Held at the Reporting Date | 14 | 11 |
Purchases, Sales and Settlements, net | 7 | 5 |
Fair value of plan assets at end of year | 168 | 147 |
Private equity | ||
Change in plan assets: | ||
Fair value of plan assets at beginning of year | 13 | 15 |
Actual Return on Plan Assets Related to Assets Still Held at the Reporting Date | (9) | (9) |
Actual Return on Plan Assets Related to Assets Sold During the Period | 9 | 10 |
Purchases, Sales and Settlements, net | (5) | (3) |
Fair value of plan assets at end of year | $ 8 | $ 13 |
Retirement Benefits (Components
Retirement Benefits (Components Of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions | 12 Months Ended | ||||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |||||
Pension Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Service cost | [1] | $ 92 | [2] | $ 79 | [2] | $ 91 | |
Interest cost | [1] | 174 | [2] | 183 | [2] | 163 | |
Expected return on plan assets | [1] | (248) | (229) | (218) | |||
Prior service credit | [1] | (1) | (1) | (2) | |||
Actuarial loss | [1] | 74 | 49 | 87 | |||
Curtailment | [1] | (12) | |||||
Settlement Loss | [1] | 1 | |||||
Net periodic benefit cost | [1] | 92 | 81 | 109 | [3] | ||
Postretirement Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Service cost | [1] | 24 | [2] | 19 | [2] | 22 | |
Interest cost | [1] | 48 | [2] | 50 | [2] | 46 | |
Expected return on plan assets | [1] | (68) | (65) | (62) | |||
Prior service credit | [1] | (5) | (5) | (6) | |||
Actuarial loss | [1] | 5 | (7) | 8 | |||
Curtailment | [1] | (7) | |||||
Settlement Loss | [1] | 0 | |||||
Net periodic benefit cost | [1] | $ 4 | $ (8) | 1 | [3] | ||
New Ameren Energy Resources Company, LLC | Pension Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Net periodic benefit cost | [1],[3] | 6 | |||||
New Ameren Energy Resources Company, LLC | Postretirement Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Net periodic benefit cost | [1],[3] | $ 7 | |||||
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries | ||||||
[2] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. | ||||||
[3] | (b)The net periodic benefit cost includes a $6 million and a $7 million net gain for pension benefits and postretirement benefits, respectively, which was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). This net gain includes the curtailment gain recognized in 2013 as a result of a significant reduction in employees as of the December 2, 2013 closing date of the New AER divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. |
Retirement Benefits (Summary 95
Retirement Benefits (Summary Of Estimated Amortizable Amounts From Regulatory Assets and Accumulated OCI Into Net Periodic Benefit Cost) (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2015USD ($) | [1] | |
Pension Benefits | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Prior service credit | $ (1) | |
Net actuarial loss | 46 | |
Net actuarial (gain) loss | (3) | |
Net periodic benefit cost | 42 | |
Postretirement Benefits | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Prior service credit | (4) | |
Net actuarial loss | (3) | |
Net actuarial (gain) loss | (2) | |
Net periodic benefit cost | $ (9) | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Retirement Benefits (Summary 96
Retirement Benefits (Summary Of Benefit Plan Costs Incurred) (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |||
Pension Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [1] | $ 92 | $ 81 | $ 109 | [2] |
Postretirement Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [1] | 4 | (8) | 1 | [2] |
Union Electric Company | Pension Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [3] | 54 | 50 | 69 | |
Union Electric Company | Postretirement Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [3] | 8 | 3 | 8 | |
Ameren Illinois Company | Pension Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | 38 | 30 | 41 | ||
Ameren Illinois Company | Postretirement Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | (3) | (9) | 0 | ||
Other | Pension Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | 0 | 1 | 5 | ||
Other | Postretirement Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | (1) | (2) | 0 | ||
Parent Company | Pension Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [4] | 92 | 81 | 115 | |
Parent Company | Postretirement Benefits | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net periodic benefit cost | [4] | $ 4 | $ (8) | $ 8 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries | ||||
[2] | (b)The net periodic benefit cost includes a $6 million and a $7 million net gain for pension benefits and postretirement benefits, respectively, which was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). This net gain includes the curtailment gain recognized in 2013 as a result of a significant reduction in employees as of the December 2, 2013 closing date of the New AER divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. | ||||
[3] | (a)Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. | ||||
[4] | (b)Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Retirement Benefits (Schedule O
Retirement Benefits (Schedule Of Expected Payments From Qualified Trust And Company Funds) (Details) $ in Millions | Dec. 31, 2015USD ($) |
Pension Benefits | Paid From Qualified Trust | |
Defined Benefit Plan Disclosure [Line Items] | |
2,016 | $ 233 |
2,017 | 244 |
2,018 | 250 |
2,019 | 257 |
2,020 | 261 |
2021 - 2025 | 1,377 |
Pension Benefits | Paid From Company Funds | |
Defined Benefit Plan Disclosure [Line Items] | |
2,016 | 3 |
2,017 | 3 |
2,018 | 3 |
2,019 | 3 |
2,020 | 3 |
2021 - 2025 | 13 |
Postretirement Benefits | Paid From Qualified Trust | |
Defined Benefit Plan Disclosure [Line Items] | |
2,016 | 55 |
2,017 | 58 |
2,018 | 60 |
2,019 | 62 |
2,020 | 65 |
2021 - 2025 | 341 |
Postretirement Benefits | Paid From Company Funds | |
Defined Benefit Plan Disclosure [Line Items] | |
2,016 | 2 |
2,017 | 2 |
2,018 | 2 |
2,019 | 2 |
2,020 | 2 |
2021 - 2025 | $ 12 |
Retirement Benefits (Assumpti98
Retirement Benefits (Assumptions Used To Determine Net Periodic Benefit Cost) (Details) | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Pension Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Discount rate at measurement date | 4.00% | 4.75% | 4.00% |
Expected return on plan assets | 7.25% | 7.25% | 7.50% |
Increase in future compensation | 3.50% | 3.50% | 3.50% |
Postretirement Benefits | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Discount rate at measurement date | 4.00% | 4.75% | 4.00% |
Expected return on plan assets | 7.00% | 7.00% | 7.25% |
Increase in future compensation | 3.50% | 3.50% | 3.50% |
Medical cost trend rate (initial) | 5.00% | 5.00% | 5.00% |
Medical cost trend rate (ultimate) | 5.00% | 5.00% | 5.00% |
Retirement Benefits (Schedule99
Retirement Benefits (Schedule Of Potential Changes In Key Assumptions) (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2015USD ($) | |
Pension Benefits | |
Defined Benefit Plan Disclosure [Line Items] | |
Service Cost and Interest Cost, .25% decrease in discount rate | $ (1) |
Benefit Obligation, .25% decrease in discount rate | 130 |
Service Cost and Interest Cost, .25% increase in salary rate | 2 |
Benefit Obligation, .25% increase in salary rate | 14 |
Postretirement Benefits | |
Defined Benefit Plan Disclosure [Line Items] | |
Service Cost and Interest Cost, .25% decrease in discount rate | 1 |
Benefit Obligation, .25% decrease in discount rate | 37 |
Service Cost and Interest Cost, 1.00% increase in annual medical trend | 3 |
Benefit Obligation, 1.00% increase in annual medical trend | 44 |
Service Cost and Interest Cost, 1.00% decrease in annual medical trend | (3) |
Benefit Obligation, 1.00% decrease in annual medical trend | $ (44) |
Retirement Benefits (Schedul100
Retirement Benefits (Schedule Of Matching Contributions) (Details) - 401 (K) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | [1] | $ 29 | $ 28 | $ 27 |
Union Electric Company | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | 16 | 16 | 16 | |
Ameren Illinois Company | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | 12 | 11 | 10 | |
Other | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | $ 1 | $ 1 | $ 1 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries. |
Stock-Based Compensation (Narra
Stock-Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||
Maximum shares available for grants | 8,000,000 | |||
Share-based compensation expense | $ 19 | $ 19 | $ 20 | |
Employee service share-based compensation, tax benefit from compensation expense | 7 | 7 | 8 | |
Amounts paid to settle share units | 27 | $ 33 | $ 11 | |
Compensation cost not yet recognized | $ 21 | |||
Expected weighted average recognition period for share-based compensation expense, in months | 23 months | |||
Performance Share Units | ||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||
Performance period | 3 years | |||
Percentage of shares issued per share unit, minimum | 0.00% | |||
Percentage of shares issued per share unit, maximum | 200.00% | |||
Fair value of each share unit, per share | $ 52.88 | [1] | $ 38.90 | |
Closing common share price | $ 46.13 | $ 36.16 | ||
Three-year risk-free rate | 1.10% | 0.78% | ||
Volatility rate, minimum | 12.00% | 12.00% | ||
Volatility rate, maximum | 18.00% | 18.00% | ||
[1] | Includes performance share units (share units) granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. |
Stock-Based Compensation (Summa
Stock-Based Compensation (Summary Of Nonvested Shares) (Details) - Performance Share Units - $ / shares | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward] | ||||
Share Units, Nonvested at beginning of year | 1,162,377 | |||
Share Units, Granted | [1] | 570,313 | ||
Share Units, Unearned or forfeited | (1,944) | |||
Share Units, Earned and vested | [2] | (705,876) | ||
Share Units, Nonvested at end of year | 1,024,870 | 1,162,377 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward] | ||||
Weighted-average Fair Value per Unit, Nonvested at beginning of year | $ 35.35 | |||
Weighted-averageFair Value per Unit, granted | 52.88 | [1] | $ 38.90 | |
Weighted-average Fair Value per Unit, Unearned or forfeited | 34.75 | |||
Weighted-average Fair Value per Unit, Earned and vested | [2] | 33.93 | ||
Weighted-average Fair Value per Unit, Nonvested at end of year | $ 46.08 | $ 35.35 | ||
Three-year risk-free rate | 1.10% | 0.78% | ||
Volatility rate, minimum | 12.00% | 12.00% | ||
Volatility rate, maximum | 18.00% | 18.00% | ||
[1] | Includes performance share units (share units) granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. | |||
[2] | Includes share units granted in 2013 that vested as of December 31, 2015, that were earned pursuant to the terms of the award grants. Also includes share units that vested due to attainment of retirement eligibility by certain employees. Actual shares issued for retirement-eligible employees will vary depending on actual performance over the three-year measurement period. |
Income Taxes (Schedule Of Effec
Income Taxes (Schedule Of Effective Income Tax Rate Reconciliation) (Details) | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Income Taxes [Line Items] | |||
Statutory federal income tax rate: | 35.00% | 35.00% | 35.00% |
Depreciation differences | (1.00%) | ||
Amortization of investment tax credit | (1.00%) | (1.00%) | (1.00%) |
State tax | 5.00% | 4.00% | 4.00% |
Other permanent items | 1.00% | 0.00% | |
Effective income tax rate | 38.00% | 39.00% | 38.00% |
Union Electric Company | |||
Income Taxes [Line Items] | |||
Statutory federal income tax rate: | 35.00% | 35.00% | 35.00% |
Depreciation differences | 0.00% | 0.00% | |
Amortization of investment tax credit | (1.00%) | (1.00%) | (1.00%) |
State tax | 3.00% | 3.00% | 3.00% |
Other permanent items | 0.00% | 0.00% | 1.00% |
Effective income tax rate | 37.00% | 37.00% | 38.00% |
Ameren Illinois Company | |||
Income Taxes [Line Items] | |||
Statutory federal income tax rate: | 35.00% | 35.00% | 35.00% |
Depreciation differences | (2.00%) | (1.00%) | |
Amortization of investment tax credit | 0.00% | 0.00% | 0.00% |
State tax | 5.00% | 6.00% | 6.00% |
Other permanent items | (1.00%) | ||
Effective income tax rate | 37.00% | 41.00% | 40.00% |
Income Taxes (Schedule Of Compo
Income Taxes (Schedule Of Components Of Income Tax Expense (Benefit)) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Income Taxes [Line Items] | ||||
Current Federal taxes | $ (2) | $ (37) | $ (118) | |
Current State taxes | (4) | (37) | 19 | |
Deferred Federal taxes | 299 | 369 | 368 | |
Deferred State taxes | 76 | 88 | 48 | |
Deferred investment tax credits, amortization | (6) | (6) | (6) | |
Total income tax expense | 363 | 377 | 311 | |
Union Electric Company | ||||
Income Taxes [Line Items] | ||||
Current Federal taxes | 110 | (13) | 136 | |
Current State taxes | 17 | (3) | 41 | |
Deferred Federal taxes | 71 | 222 | 64 | |
Deferred State taxes | 16 | 28 | 6 | |
Deferred investment tax credits, amortization | (5) | (5) | (5) | |
Total income tax expense | 209 | 229 | 242 | |
Ameren Illinois Company | ||||
Income Taxes [Line Items] | ||||
Current Federal taxes | (83) | (51) | (15) | |
Current State taxes | (11) | (2) | 21 | |
Deferred Federal taxes | 193 | 159 | 99 | |
Deferred State taxes | 29 | 38 | 6 | |
Deferred investment tax credits, amortization | (1) | (1) | (1) | |
Total income tax expense | 127 | 143 | 110 | |
Other | ||||
Income Taxes [Line Items] | ||||
Current Federal taxes | (29) | 27 | (239) | [1] |
Current State taxes | (10) | (32) | (43) | [1] |
Deferred Federal taxes | 35 | (12) | 205 | [1] |
Deferred State taxes | 31 | 22 | 36 | [1] |
Deferred investment tax credits, amortization | 0 | 0 | 0 | |
Total income tax expense | $ 27 | $ 5 | $ (41) | |
[1] | These amounts are substantially related to the reversal of unrecognized tax benefits as a result of IRS guidance related to the deductibility of expenditures to maintain, replace, or improve steam or electric power generation property, along with casualty loss deductions for storm damage. The amounts also reflect the increase in deferred tax expense due to available net operating losses. |
Income Taxes (Schedule Of Defer
Income Taxes (Schedule Of Deferred Tax Assets And Liabilities Resulting From Temporary Differences) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | |
Income Taxes [Line Items] | |||
Plant related | $ 4,555 | $ 4,185 | |
Regulatory assets, net | 80 | 78 | |
Deferred benefit costs | (207) | (220) | |
Revenue Requirement Reconciliation Adjustment | 66 | 69 | |
ARO | (603) | (675) | |
Other | 134 | ||
Other | (6) | ||
Total net accumulated deferred income tax liabilities | [1] | 3,885 | 3,571 |
Union Electric Company | |||
Income Taxes [Line Items] | |||
Plant related | 2,931 | 2,776 | |
Regulatory assets, net | 81 | 82 | |
Deferred benefit costs | (76) | (80) | |
ARO | (65) | (107) | |
Other | 86 | ||
Other | (27) | ||
Total net accumulated deferred income tax liabilities | [1] | 2,844 | 2,757 |
Ameren Illinois Company | |||
Income Taxes [Line Items] | |||
Plant related | 1,587 | 1,393 | |
Regulatory assets, net | (1) | (5) | |
Deferred benefit costs | (40) | (45) | |
Revenue Requirement Reconciliation Adjustment | 66 | 66 | |
ARO | (133) | (139) | |
Other | 1 | ||
Other | (22) | ||
Total net accumulated deferred income tax liabilities | [1] | 1,480 | 1,248 |
Other | |||
Income Taxes [Line Items] | |||
Plant related | 37 | 16 | |
Regulatory assets, net | 1 | ||
Deferred benefit costs | (91) | (95) | |
Revenue Requirement Reconciliation Adjustment | 0 | 3 | |
ARO | (405) | (429) | |
Other | 20 | 70 | |
Total net accumulated deferred income tax liabilities | [1] | $ (439) | $ (434) |
[1] | Reflects the adoption of the new authoritative accounting guidance for the balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. |
Income Taxes (Schedule Of Net O
Income Taxes (Schedule Of Net Operating Loss Carryforwards And Tax Credit Carryforwards) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | |||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | $ 453 | $ 531 | ||
Tax credit carryforwards | $ 144 | $ 131 | ||
Tax credit carryforward, expiration period start | Jan. 1, 2016 | Jan. 1, 2013 | ||
Deferred Tax Assets, Charitable Contribution Carryforwards | $ 10 | [1] | $ 19 | [2] |
Deferred Tax Assets, Valuation Allowance, Noncurrent | (4) | [3] | 6 | [4] |
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 6 | 13 | ||
Federal | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 407 | [5] | 457 | [6] |
Tax credit carryforwards | $ 105 | [7] | $ 99 | [8] |
Net operating loss carryforward, expiration period start | Jan. 1, 2029 | Jan. 1, 2028 | ||
Tax credit carryforward, expiration period start | Jan. 1, 2029 | Jan. 1, 2029 | ||
State | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | $ 46 | [9] | $ 74 | [10] |
Tax credit carryforwards | 41 | [11] | 36 | [12] |
Tax Credit Carryforward, Valuation Allowance | $ (2) | [3] | $ 4 | [4] |
Net operating loss carryforward, expiration period start | Jan. 1, 2023 | Jan. 1, 2019 | ||
Tax credit carryforward, expiration period start | Jan. 1, 2016 | Jan. 1, 2013 | ||
Union Electric Company | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | $ 39 | $ 86 | ||
Tax credit carryforwards | 26 | 21 | ||
Union Electric Company | Federal | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 35 | [5] | 75 | [6] |
Tax credit carryforwards | 26 | [7] | 21 | [8] |
Union Electric Company | State | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 4 | [9] | 11 | [10] |
Tax credit carryforwards | 0 | [11] | 1 | [12] |
Tax Credit Carryforward, Valuation Allowance | 0 | [3] | (1) | [4] |
Ameren Illinois Company | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 131 | 137 | ||
Tax credit carryforwards | 2 | 2 | ||
Ameren Illinois Company | Federal | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 127 | [5] | 127 | [6] |
Tax credit carryforwards | 1 | [7] | 1 | [8] |
Ameren Illinois Company | State | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 4 | [9] | 10 | [10] |
Tax credit carryforwards | 1 | [11] | 2 | [12] |
Tax Credit Carryforward, Valuation Allowance | 0 | [3] | (1) | [4] |
Other | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 283 | 308 | ||
Tax credit carryforwards | 116 | 108 | ||
Deferred Tax Assets, Charitable Contribution Carryforwards | 10 | [1] | 19 | [2] |
Deferred Tax Assets, Valuation Allowance, Noncurrent | (4) | [3] | (6) | [4] |
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 6 | 13 | ||
Other | Federal | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 245 | [5] | 255 | [6] |
Tax credit carryforwards | 78 | [7] | 77 | [8] |
Other | State | ||||
Operating Loss Carryforwards [Line Items] | ||||
Net operating loss carryforwards | 38 | [9] | 53 | [10] |
Tax credit carryforwards | 40 | [11] | 33 | [12] |
Tax Credit Carryforward, Valuation Allowance | $ (2) | [3] | $ (2) | [4] |
[1] | (f)Will begin to expire in 2016. | |||
[2] | (f)Began to expire in 2013. | |||
[3] | See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. | |||
[4] | See Schedule II under Part IV, Item 15, in this report for information on changes in the valuation allowance. | |||
[5] | Will begin to expire in 2029. | |||
[6] | Will begin to expire in 2028 | |||
[7] | Will begin to expire in 2029 | |||
[8] | Will begin to expire in 2029 | |||
[9] | Will begin to expire in 2023 | |||
[10] | Will begin to expire in 2019 | |||
[11] | Will begin to expire in 2016 | |||
[12] | Began to expire in 2013 |
Income Taxes (Schedule Of Chang
Income Taxes (Schedule Of Changes To Unrecognized Tax Benefits And Related Interest) (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | ||||||
Unrecognized tax benefits | $ 54 | $ 90 | $ 156 | |||
Increases based on tax positions | 2 | 6 | 7 | |||
Decreases based on tax positions | 56 | 42 | 143 | |||
Increases based on tax positions related to current period | 0 | 69 | ||||
Decreases related to the lapse of statute of limitations | 1 | |||||
Unrecognized tax benefits | 0 | 54 | 90 | |||
Total unrecognized tax benefits (detriments) that, if recognized, would impact the effective tax rates | 0 | 52 | 54 | |||
Union Electric Company | ||||||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | ||||||
Unrecognized tax benefits | 0 | 31 | 136 | |||
Increases based on tax positions | 0 | 1 | 0 | |||
Decreases based on tax positions | 0 | 32 | 122 | |||
Increases based on tax positions related to current period | 0 | 0 | 16 | |||
Changes related to settlements with taxing authorities | 0 | |||||
Decreases related to the lapse of statute of limitations | 1 | |||||
Unrecognized tax benefits | 0 | 0 | 31 | |||
Total unrecognized tax benefits (detriments) that, if recognized, would impact the effective tax rates | 0 | 0 | 3 | |||
Ameren Illinois Company | ||||||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | ||||||
Unrecognized tax benefits | (1) | (1) | 13 | |||
Increases based on tax positions | 1 | 1 | 2 | |||
Decreases based on tax positions | 0 | 1 | 16 | |||
Increases based on tax positions related to current period | 0 | 0 | ||||
Changes related to settlements with taxing authorities | 0 | |||||
Unrecognized tax benefits | 0 | (1) | (1) | |||
Total unrecognized tax benefits (detriments) that, if recognized, would impact the effective tax rates | 0 | (1) | ||||
Other | ||||||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | ||||||
Unrecognized tax benefits | 55 | 60 | 7 | |||
Increases based on tax positions | 1 | 4 | 5 | |||
Decreases based on tax positions | (56) | [1] | 9 | 5 | ||
Increases based on tax positions related to current period | 0 | 53 | [1] | |||
Changes related to settlements with taxing authorities | 0 | |||||
Unrecognized tax benefits | 0 | 55 | 60 | |||
Total unrecognized tax benefits (detriments) that, if recognized, would impact the effective tax rates | $ 0 | $ 53 | [1] | $ 51 | [1] | |
[1] | Primarily due to tax positions relating to the New AER divestiture. The income statement impact of this unrecognized tax benefit was included in "Income (loss) from discontinued operations, net of taxes" on Ameren's consolidated statement of income (loss). See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. |
Income Taxes (Reconciliation Of
Income Taxes (Reconciliation Of The Change In The Liability For Interest On Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Income Tax Contingency [Line Items] | |||
Liability for interest | $ 0 | $ 1 | $ 6 |
Interest charges (income) | (1) | (5) | |
Liability for interest | 0 | 0 | 1 |
Union Electric Company | |||
Income Tax Contingency [Line Items] | |||
Liability for interest | 0 | 0 | 8 |
Interest charges (income) | 0 | 0 | (8) |
Liability for interest | 0 | 0 | 0 |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 0 | ||
Ameren Illinois Company | |||
Income Tax Contingency [Line Items] | |||
Liability for interest | 0 | 0 | 1 |
Interest charges (income) | 0 | (1) | |
Liability for interest | 0 | 0 | 0 |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 0 | ||
Other | |||
Income Tax Contingency [Line Items] | |||
Liability for interest | 0 | 1 | (3) |
Interest charges (income) | (1) | 4 | |
Liability for interest | $ 0 | 0 | $ 1 |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 0 | ||
2007 through 2011 tax year | Ameren Corporation [Member] | |||
Income Tax Contingency [Line Items] | |||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 20 | ||
2007 through 2011 tax year | Union Electric Company | |||
Income Tax Contingency [Line Items] | |||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 13 | ||
Tax Year 2012 [Member] | Union Electric Company | |||
Income Tax Contingency [Line Items] | |||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | $ 18 |
Income Taxes (Narrative) (Detai
Income Taxes (Narrative) (Details) - USD ($) $ in Millions | 1 Months Ended | 12 Months Ended | ||
Jan. 31, 2011 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Income Taxes [Line Items] | ||||
State corporate income tax rate | 5.00% | 4.00% | 4.00% | |
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions | $ 103 | |||
Maximum | Illinois Corporate Income Tax | ||||
Income Taxes [Line Items] | ||||
State corporate income tax rate | 9.50% | |||
Union Electric Company | ||||
Income Taxes [Line Items] | ||||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | $ 0 | |||
State corporate income tax rate | 3.00% | 3.00% | 3.00% | |
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions | $ 95 | |||
Ameren Illinois Company | ||||
Income Taxes [Line Items] | ||||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | $ 0 | |||
State corporate income tax rate | 5.00% | 6.00% | 6.00% | |
Unrecognized Tax Benefits, Decrease Resulting from Current Period Tax Positions | $ 5 | |||
Income Tax Rate in 2015 | Illinois Corporate Income Tax | ||||
Income Taxes [Line Items] | ||||
State corporate income tax rate | 7.75% | |||
Income Tax Rate in 2025 | Illinois Corporate Income Tax | ||||
Income Taxes [Line Items] | ||||
State corporate income tax rate | 7.30% | |||
State | ||||
Income Taxes [Line Items] | ||||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | $ 53 | $ 2 |
Related Party Transactions (Det
Related Party Transactions (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||||
Union Electric Company | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | $ 42 | $ 27 | $ 25 | |||
Operating Expenses | 131 | 124 | 116 | |||
Union Electric Company | Ameren Missouri Power Supply Agreements with Ameren Illinois | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 15 | 5 | 3 | |||
Union Electric Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 25 | 21 | 21 | |||
Union Electric Company | Ameren Missouri and Ameren Illinois miscellaneous support services | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 2 | 1 | 1 | |||
Union Electric Company | Ameren Services Support Services Agreement | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Expenses | 131 | 124 | 116 | |||
Union Electric Company | Money Pool | ||||||
Related Party Transaction [Line Items] | ||||||
Interest (Charges) Income | [1] | 1 | 1 | 1 | ||
Ameren Illinois Company | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 4 | 2 | 4 | |||
Operating Expenses | 119 | 109 | 93 | |||
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 4 | 2 | 1 | |||
Ameren Illinois Company | Ameren Missouri and Ameren Illinois miscellaneous support services | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Revenues | 1 | [1] | 1 | [1] | 3 | |
Ameren Illinois Company | Ameren Illinois Power Supply Agreements with Ameren Missouri | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Expenses | 15 | 5 | 3 | |||
Ameren Illinois Company | Ameren Illinois transmission agreements with ATXI | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Expenses | 2 | 2 | 2 | |||
Ameren Illinois Company | Purchased Power | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Expenses | 17 | 7 | 5 | |||
Ameren Illinois Company | Ameren Services Support Services Agreement | ||||||
Related Party Transaction [Line Items] | ||||||
Operating Expenses | 119 | 109 | 93 | |||
Ameren Illinois Company | Money Pool | ||||||
Related Party Transaction [Line Items] | ||||||
Interest (Charges) Income | [1] | $ 1 | $ 1 | $ 1 | ||
[1] | Amount less than $1 million. |
Related Party Transactions (Nar
Related Party Transactions (Narrative) (Details) $ in Millions | 1 Months Ended | 3 Months Ended | 12 Months Ended | ||||
Apr. 30, 2012USD ($) | May. 31, 2011MWh$ / MWh | Apr. 30, 2010USD ($) | Dec. 31, 2015MWh$ / MWh | Dec. 31, 2015USD ($)MWh$ / MWh | Dec. 31, 2014USD ($) | Dec. 31, 2013USD ($) | |
Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Noncash Or Part Noncash Capital Contribution From Parent | $ | $ 38 | $ 9 | $ 0 | ||||
Period Five | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Energy Supply Agreements Amount | $ | $ 1 | ||||||
Period Five | Ameren Illinois Company | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | MWh | 40,800 | ||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 28 | ||||||
Period Six | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Energy Supply Agreements Amount | $ | $ 3 | ||||||
Period Seven [Member] | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Energy Supply Agreements Amount | $ | $ 15 | ||||||
Period Four | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Energy Supply Agreements Amount | $ | $ 1 | ||||||
Period Four | Ameren Illinois Company | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | MWh | 40,800 | ||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 29 | ||||||
Ameren Illinois Power Supply Agreements with Ameren Missouri | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | MWh | 168,400 | ||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 51 | ||||||
April 2015 Procurement [Member] | Ameren Illinois Power Supply Agreements with Ameren Missouri | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | MWh | 667,000 | ||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 36 | ||||||
September 2015 Procurement [Member] | Ameren Illinois Power Supply Agreements with Ameren Missouri | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | MWh | 339,000 | ||||||
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 38 |
Commitments And Contingencie112
Commitments And Contingencies (Callaway Nuclear Energy Center) (Details) | 12 Months Ended | |
Dec. 31, 2015USD ($) | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | $ 13,489,000,000 | [1] |
Insurance maximum coverage per incident | 127,000,000 | |
Threshold Amount For Retrospective Insurance Assessment For Covered Loss Under Public Liability And Nuclear Worker Liability Insurance Policy | 375,000,000 | |
Annual payment in the event of an incident at any licensed commercial reactor | 19,000,000 | |
Aggregate maximum assessment per incident under Price-Anderson liability provisions of Atomic Energy Act | 127,000,000 | |
Maximum annual payment to be paid in a calendar year per reactor incident under liability provisions of Atomic Energy Act | 19,000,000 | |
Amount of coverage in excess of primary property liability coverage | 2,250,000,000 | |
Amount of weekly indemnity coverage commencing eight weeks after power outage | $ 4,500,000 | |
Number of weeks of coverage after the first eight weeks of an outage | 1 year | |
Amount of additional weekly indemnity coverage commencing after initial indemnity coverage | $ 3,600,000 | |
Number of additional weeks after initial indemnity coverage for power outage, minimum | 1 year 4 months 10 days | |
Amount of weekly indemnity coverage thereafter not exceeding policy limit | $ 490,000,000 | |
Aggregate nuclear power industry insurance policy limit for losses from terrorist attacks within twelve month period | 3,240,000,000 | |
Public Liability And Nuclear Worker Liability - American Nuclear Insurers | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 375,000,000 | |
Insurance maximum coverage per incident | 0 | |
Public Liability And Nuclear Worker Liability - Pool Participation | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 13,114,000,000 | [2] |
Insurance maximum coverage per incident | 127,000,000 | [3] |
Property Damage - Nuclear Electric Insurance Ltd | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 2,750,000,000 | [4] |
Insurance maximum coverage per incident | 27,000,000 | [5] |
Replacement Power - Nuclear Electric Insurance Ltd | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 490,000,000 | [6] |
Insurance maximum coverage per incident | 10,000,000 | [5] |
Sub-limit of Amount of Weekly indemnity Coverage Thereafter Not Exceeding Policy Limit for Non-Nuclear Events | 328,000,000 | |
Property Damage European Mutual Association for Nuclear Insurance | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 500,000,000 | [7] |
Amount of primary property liability coverage | 500,000,000 | |
Radiation Event | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 500,000,000 | |
Property Damage | ||
Commitments and Contingencies [Line Items] | ||
Insurance aggregate maximum coverage | 3,250,000,000 | |
Insurance maximum coverage per incident | 27,000,000 | |
Non-radiation event | ||
Commitments and Contingencies [Line Items] | ||
Aggregate nuclear power industry insurance policy limit for losses from terrorist attacks within twelve month period | $ 1,830,000,000 | |
[1] | Limit of liability for each incident under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended. A company could be assessed up to $127 million per incident for each licensed reactor it operates, with a maximum of $19 million per incident to be paid in a calendar year for each reactor. This limit is subject to change to account for the effects of inflation and changes in the number of licensed reactors. | |
[2] | Provided through mandatory participation in an industrywide retrospective premium assessment program. | |
[3] | Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $375 million in the event of an incident at any licensed United States commercial reactor, payable at $19 million per year. | |
[4] | NEIL provides $2.25 billion in property damage, decontamination, and premature decommissioning insurance for both radiation and nonradiation events. An additional $500 million is provided for radiation events only for a total of $2.75 billion. | |
[5] | All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. | |
[6] | Provides replacement power cost insurance in the event of a prolonged accidental outage. Weekly indemnity is up to $4.5 million for 52 weeks, which commences after the first twelve weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter, for a total not exceeding the policy limit of $490 million. Nonradiation events are sub-limited to $328 million. | |
[7] | European Mutual Association for Nuclear Insurance provides $500 million in excess of the $2.75 billion and $2.25 billion property coverage for radiation and nonradiation events, respectively, provided by NEIL. |
Commitments And Contingencie113
Commitments And Contingencies (Schedule Of Lease Obligations) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Commitments and Contingencies [Line Items] | ||||
Capital lease payments, due in one year | [1],[2] | $ 33 | ||
Capital lease payments, due in two years | [1],[2] | 33 | ||
Capital lease payments, due in three years | [1],[2] | 32 | ||
Capital lease payments, due in four years | [1],[2] | 32 | ||
Capital lease payments, due in five years | [1],[2] | 32 | ||
Capital lease payments, After 5 Years | [1],[2] | 329 | ||
Capital lease payments, Total | [1],[2] | 491 | ||
Less Amount representing interest, due in one year | [2] | 27 | ||
Less Amount representing interest, due in two years | [2] | 27 | ||
Less Amount representing interest, due in three years | [2] | 26 | ||
Less Amount representing interest, due in four years | [2] | 25 | ||
Less Amount representing interest, due in 5 years | [2] | 25 | ||
Less Amount representing interest, After 5 Years | [2] | 73 | ||
Less Amount representing interest, Total | [2] | 203 | ||
Present value of minimum capital lease payments, due in one year | [2] | 6 | ||
Present value of minimum capital lease payments, due in two years | [2] | 6 | ||
Present value of minimum capital lease payments, due in three years | [2] | 6 | ||
Present value of minimum capital lease payments, due in four years | [2] | 7 | ||
Present value of minimum capital lease payments, due in five years | [2] | 7 | ||
Present value of minimum capital lease payments, After 5 Years | [2] | 256 | ||
Present value of minimum capital lease payments, Total | [2] | 288 | ||
Operating leases, due in one year | [2],[3] | 14 | ||
Operating leases, due in two years | [2],[3] | 13 | ||
Operating leases, due in three years | [2],[3] | 12 | ||
Operating leases, due in four years | [2],[3] | 12 | ||
Operating leases, due in five years | [2],[3] | 11 | ||
Operating leases, After 5 Years | [2],[3] | 30 | ||
Operating leases, Total | [2],[3] | 92 | ||
Total lease obligations, due in one year | [2] | 20 | ||
Total lease obligations, due in two years | [2] | 19 | ||
Total lease obligations, due in three years | [2] | 18 | ||
Total lease obligations, due in four years | [2] | 19 | ||
Total lease obligations, due in five years | [2] | 18 | ||
Total lease obligations, After 5 Years | [2] | 286 | ||
Total lease obligations, Total | [2] | 380 | ||
Annual obligation for real estate leases and railroad licenses | 3 | |||
Total rental expense | [4] | 36 | $ 37 | $ 32 |
Union Electric Company | ||||
Commitments and Contingencies [Line Items] | ||||
Capital lease payments, due in one year | [1] | 33 | ||
Capital lease payments, due in two years | [1] | 33 | ||
Capital lease payments, due in three years | [1] | 32 | ||
Capital lease payments, due in four years | [1] | 32 | ||
Capital lease payments, due in five years | [1] | 32 | ||
Capital lease payments, After 5 Years | [1] | 329 | ||
Capital lease payments, Total | [1] | 491 | ||
Less Amount representing interest, due in one year | 27 | |||
Less Amount representing interest, due in two years | 27 | |||
Less Amount representing interest, due in three years | 26 | |||
Less Amount representing interest, due in four years | 25 | |||
Less Amount representing interest, due in 5 years | 25 | |||
Less Amount representing interest, After 5 Years | 73 | |||
Less Amount representing interest, Total | 203 | |||
Present value of minimum capital lease payments, due in one year | 6 | |||
Present value of minimum capital lease payments, due in two years | 6 | |||
Present value of minimum capital lease payments, due in three years | 6 | |||
Present value of minimum capital lease payments, due in four years | 7 | |||
Present value of minimum capital lease payments, due in five years | 7 | |||
Present value of minimum capital lease payments, After 5 Years | 256 | |||
Present value of minimum capital lease payments, Total | 288 | |||
Operating leases, due in one year | [3] | 12 | ||
Operating leases, due in two years | [3] | 11 | ||
Operating leases, due in three years | [3] | 11 | ||
Operating leases, due in four years | [3] | 11 | ||
Operating leases, due in five years | [3] | 10 | ||
Operating leases, After 5 Years | [3] | 29 | ||
Operating leases, Total | [3] | 84 | ||
Total lease obligations, due in one year | 18 | |||
Total lease obligations, due in two years | 17 | |||
Total lease obligations, due in three years | 17 | |||
Total lease obligations, due in four years | 18 | |||
Total lease obligations, due in five years | 17 | |||
Total lease obligations, After 5 Years | 285 | |||
Total lease obligations, Total | 372 | |||
Annual obligation for real estate leases and railroad licenses | 2 | |||
Total rental expense | 34 | 32 | 29 | |
Ameren Illinois Company | ||||
Commitments and Contingencies [Line Items] | ||||
Operating leases, due in one year | [3] | 1 | ||
Operating leases, due in two years | [3] | 1 | ||
Operating leases, due in three years | [3] | 1 | ||
Operating leases, due in four years | [3] | 1 | ||
Operating leases, due in five years | [3] | 1 | ||
Operating leases, After 5 Years | [3] | 1 | ||
Operating leases, Total | [3] | 6 | ||
Annual obligation for real estate leases and railroad licenses | 1 | |||
Total rental expense | $ 28 | $ 25 | $ 21 | |
[1] | See Properties under Part I, Item 2, and Note 3 – Property and Plant, Net, of this report for additional information. | |||
[2] | ncludes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. | |||
[3] | Amounts related to certain land-related leases have indefinite payment periods. The annual obligations of $3 million, $2 million, and $1 million for Ameren, Ameren Missouri, and Ameren Illinois for these items are included in the 2016 through 2020 columns, respectively. | |||
[4] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Commitments And Contingencie114
Commitments And Contingencies (Schedule Of Estimated Purchased Power Commitments) (Details) $ in Millions | Dec. 31, 2015USD ($) | |
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | $ 1,323 | [1] |
2,017 | 1,145 | [1] |
2,018 | 531 | [1] |
2,019 | 342 | [1] |
2,020 | 215 | [1] |
Thereafter | 1,128 | [1] |
Total | 4,684 | [1] |
Coal | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 664 | [1] |
2,017 | 685 | [1] |
2,018 | 204 | [1] |
2,019 | 110 | [1] |
2,020 | 0 | [1] |
Thereafter | 0 | [1] |
Total | 1,663 | [1] |
Natural Gas | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 249 | [1],[2] |
2,017 | 190 | [1],[2] |
2,018 | 127 | [1],[2] |
2,019 | 89 | [1],[2] |
2,020 | 43 | [1],[2] |
Thereafter | 60 | [1],[2] |
Total | 758 | [1],[2] |
Nuclear Fuel | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 51 | [1] |
2,017 | 46 | [1] |
2,018 | 68 | [1] |
2,019 | 24 | [1] |
2,020 | 51 | [1] |
Thereafter | 108 | [1] |
Total | 348 | [1] |
Purchased Power | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 241 | [1],[3] |
2,017 | 147 | [1],[3] |
2,018 | 72 | [1],[3] |
2,019 | 58 | [1],[3] |
2,020 | 58 | [1],[3] |
Thereafter | 539 | [1],[3] |
Total | 1,115 | [1],[3] |
Methane Gas | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 3 | [1] |
2,017 | 4 | [1] |
2,018 | 5 | [1] |
2,019 | 5 | [1] |
2,020 | 6 | [1] |
Thereafter | 71 | [1] |
Total | 94 | [1] |
Other | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 115 | [1] |
2,017 | 73 | [1] |
2,018 | 55 | [1] |
2,019 | 56 | [1] |
2,020 | 57 | [1] |
Thereafter | 350 | [1] |
Total | 706 | [1] |
Union Electric Company | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 833 | |
2,017 | 826 | |
2,018 | 352 | |
2,019 | 205 | |
2,020 | 120 | |
Thereafter | 469 | |
Total | 2,805 | |
Union Electric Company | Coal | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 664 | |
2,017 | 685 | |
2,018 | 204 | |
2,019 | 110 | |
2,020 | 0 | |
Thereafter | 0 | |
Total | 1,663 | |
Union Electric Company | Natural Gas | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 46 | [2] |
2,017 | 36 | [2] |
2,018 | 24 | [2] |
2,019 | 14 | [2] |
2,020 | 10 | [2] |
Thereafter | 23 | [2] |
Total | 153 | [2] |
Union Electric Company | Nuclear Fuel | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 51 | |
2,017 | 46 | |
2,018 | 68 | |
2,019 | 24 | |
2,020 | 51 | |
Thereafter | 108 | |
Total | 348 | |
Union Electric Company | Purchased Power | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 23 | |
2,017 | 23 | |
2,018 | 23 | |
2,019 | 23 | |
2,020 | 23 | |
Thereafter | 84 | |
Total | 199 | |
Union Electric Company | Methane Gas | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 3 | |
2,017 | 4 | |
2,018 | 5 | |
2,019 | 5 | |
2,020 | 6 | |
Thereafter | 71 | |
Total | 94 | |
Union Electric Company | Other | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 46 | |
2,017 | 32 | |
2,018 | 28 | |
2,019 | 29 | |
2,020 | 30 | |
Thereafter | 183 | |
Total | 348 | |
Ameren Illinois Company | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 452 | |
2,017 | 303 | |
2,018 | 176 | |
2,019 | 137 | |
2,020 | 95 | |
Thereafter | 659 | |
Total | 1,822 | |
Ameren Illinois Company | Natural Gas | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 203 | [2] |
2,017 | 154 | [2] |
2,018 | 103 | [2] |
2,019 | 75 | [2] |
2,020 | 33 | [2] |
Thereafter | 37 | [2] |
Total | 605 | [2] |
Ameren Illinois Company | Purchased Power | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 218 | [3] |
2,017 | 124 | [3] |
2,018 | 49 | [3] |
2,019 | 35 | [3] |
2,020 | 35 | [3] |
Thereafter | 455 | [3] |
Total | 916 | [3] |
Ameren Illinois Company | Other | ||
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract] | ||
2,016 | 31 | |
2,017 | 25 | |
2,018 | 24 | |
2,019 | 27 | |
2,020 | 27 | |
Thereafter | 167 | |
Total | $ 301 | |
[1] | (c)Includes amounts for Ameren registrant and nonregistrant subsidiaries. | |
[2] | (a)Includes amounts for generation and for distribution. | |
[3] | (b)The purchased power amounts for Ameren and Ameren Illinois include agreements through 2032 for renewable energy credits with various renewable energy suppliers. The agreements contain a provision that allows Ameren Illinois to reduce the quantity purchased in the event that Ameren Illinois would not be able to recover the costs associated with the renewable energy credits. |
Commitments And Contingencie115
Commitments And Contingencies (Environmental Matters) (Details) $ in Millions | Dec. 31, 2015USD ($)site |
Manufactured Gas Plant | |
Accrual for environmental loss contingencies | $ 232 |
Manufactured Gas Plant | Ameren Illinois Company | |
Number of remediation sites | site | 44 |
Loss contingency range of possible loss, minimum | $ 232 |
Loss contingency range of possible loss, maximum | 313 |
Accrual for environmental loss contingencies | 232 |
Former Coal Ash Landfill | Ameren Illinois Company | |
Loss contingency range of possible loss, minimum | 0.5 |
Loss contingency range of possible loss, maximum | 6 |
Accrual for environmental loss contingencies | 0.5 |
Other Environmental | Ameren Illinois Company | |
Accrual for environmental loss contingencies | 0.7 |
Former Coal Tar Distillery | Union Electric Company | |
Loss contingency range of possible loss, minimum | 2 |
Loss contingency range of possible loss, maximum | 5 |
Accrual for environmental loss contingencies | 2 |
Sauget Area 2 | Union Electric Company | |
Loss contingency range of possible loss, minimum | 1 |
Loss contingency range of possible loss, maximum | 2.5 |
Accrual for environmental loss contingencies | 1 |
Substation in St Charles, Missouri | Union Electric Company | |
Accrual for environmental loss contingencies | 0.6 |
Minimum | |
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 600 |
Maximum | |
Estimated capital costs to comply with existing and known federal and state air emissions regulations | $ 700 |
Commitments And Contingencie116
Commitments And Contingencies (Pumped-Storage Hydroelectric Facility Breach) (Details) - Union Electric Company - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2016 | Dec. 31, 2015 | |
Commitments and Contingencies [Line Items] | ||
Insurance Settlements Receivable | $ 41 | |
Subsequent Event | ||
Commitments and Contingencies [Line Items] | ||
Litigation Settlement, Amount | $ 42 |
Commitments And Contingencie117
Commitments And Contingencies (Asbestos-Related Litigation And Tax Exemptions And Credits) (Details) - Asbestos-Related $ in Millions | 12 Months Ended | |
Dec. 31, 2015USD ($)defendant | ||
Loss Contingencies [Line Items] | ||
Number of defendants | defendant | 75 | |
Number of pending asbestos lawsuits as of the balance sheet date | 48 | [1] |
Loss contingency range of possible loss, minimum | $ 8 | |
Percent of allowed cash expenditures in excess of base rates to be recovered through charges assessed to customers | 90.00% | |
Asbestos trust fund balance | $ 22 | |
Percent of difference to be contributed to the asbestos trust fund if cash expenditures are less than amount included in base electric rates. | 90.00% | |
Union Electric Company | ||
Loss Contingencies [Line Items] | ||
Number of pending asbestos lawsuits as of the balance sheet date | 26 | |
Loss contingency range of possible loss, minimum | $ 3 | |
Ameren Illinois Company | ||
Loss Contingencies [Line Items] | ||
Number of pending asbestos lawsuits as of the balance sheet date | 38 | |
Loss contingency range of possible loss, minimum | $ 5 | |
[1] | (a)Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. |
Divestiture Transactions and118
Divestiture Transactions and Discontinued Operations (Narrative) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | |
Jan. 31, 2014 | Dec. 31, 2013 | Dec. 31, 2015 | |
New Ameren Energy Resources Company, LLC | |||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Loss Contingency Accrual | $ 25 | ||
Elgin, Gibson City and Grand Tower Energy Centers | |||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Proceeds from Sales of Business, Affiliate and Productive Assets | $ 168 | $ 137.5 |
Divestiture Transactions and119
Divestiture Transactions and Discontinued Operations (Components of Discontinued Operations in Consolidated Statement of Income) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Operating revenues | $ 0 | $ 1 | $ 1,037 | |
Operating benefits (expenses) | 1 | (2) | (1,207) | [1] |
Operating income (loss) | 1 | (1) | (170) | |
Other income (loss) | 0 | 0 | (1) | |
Interest charges | 0 | 0 | (39) | |
Income (loss) before income taxes | 1 | (1) | (210) | |
Income tax (expense) benefit | 50 | 0 | (13) | |
Income (Loss) from Discontinued Operations, Net of Tax (Note 16) | $ 51 | $ (1) | (223) | |
Merchant Generation | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Impairment of assets to be disposed of | $ 201 | |||
[1] | (a)Includes a $201 million pretax loss on disposal relating to the New AER divestiture. |
Divestiture Transactions and120
Divestiture Transactions and Discontinued Operations (Components of Assets and Liabilities on Consolidated Balance Sheet) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Assets of discontinued operations | ||||
Accumulated deferred income taxes, net | $ 14 | $ 15 | ||
Total assets of discontinued operations | 14 | 15 | $ 165 | |
Liabilities of discontinued operations | ||||
Accounts payable and other current obligations | 1 | 1 | ||
Asset retirement obligations | [1] | 28 | 32 | |
Total liabilities of discontinued operations | $ 29 | $ 33 | ||
[1] | (a)Ameren is demolishing the Hutsonville energy center and expects to demolish the Meredosia energy center beginning in 2016. |
Segment Information (Details)
Segment Information (Details) $ in Millions | 3 Months Ended | 12 Months Ended | ||||||||||
Dec. 31, 2015USD ($) | Sep. 30, 2015USD ($) | Jun. 30, 2015USD ($) | Mar. 31, 2015USD ($) | Dec. 31, 2014USD ($) | Sep. 30, 2014USD ($) | Jun. 30, 2014USD ($) | Mar. 31, 2014USD ($) | Dec. 31, 2015USD ($)segment | Dec. 31, 2014USD ($) | Dec. 31, 2013USD ($) | ||
Segment Reporting Information [Line Items] | ||||||||||||
Number of reportable segments | segment | 2 | |||||||||||
External revenues | $ 1,308 | $ 1,833 | $ 1,401 | $ 1,556 | $ 1,370 | $ 1,670 | $ 1,419 | $ 1,594 | $ 6,098 | $ 6,053 | $ 5,838 | |
Depreciation and amortization | 796 | 745 | 706 | |||||||||
Interest Expense | 355 | 341 | 398 | |||||||||
Income taxes (benefit) | 363 | 377 | 311 | |||||||||
Net income (loss) attributable to Ameren common shareholders | 29 | 343 | 150 | 108 | 48 | 293 | 149 | 96 | 630 | 586 | 289 | |
Capital expenditures | 1,917 | 1,785 | 1,379 | |||||||||
TOTAL ASSETS | 23,640 | 22,289 | 23,640 | 22,289 | ||||||||
Assets of discontinued operations (Note 16) | 14 | 15 | 14 | 15 | 165 | |||||||
Net income (loss) attributable to Ameren common shareholders - continuing operations | 30 | $ 343 | $ 98 | $ 108 | 46 | $ 294 | $ 150 | $ 97 | $ 579 | 587 | 512 | |
Union Electric Company | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Number of reportable segments | 1 | |||||||||||
External revenues | $ 3,566 | 3,526 | 3,516 | |||||||||
Revenue from Related Parties | 43 | 27 | 25 | |||||||||
Depreciation and amortization | 492 | 473 | 454 | |||||||||
Interest and dividend income | 28 | 28 | 27 | |||||||||
Interest Expense | 219 | 211 | 210 | |||||||||
Income taxes (benefit) | 209 | 229 | 242 | |||||||||
Net income (loss) attributable to Ameren common shareholders | 352 | 390 | 395 | |||||||||
Capital expenditures | 622 | 747 | 648 | |||||||||
TOTAL ASSETS | [1] | 13,851 | 13,474 | $ 13,851 | 13,474 | 12,867 | ||||||
Ameren Illinois Company | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Number of reportable segments | 1 | |||||||||||
External revenues | $ 2,462 | 2,496 | 2,307 | |||||||||
Revenue from Related Parties | 4 | 2 | 4 | |||||||||
Depreciation and amortization | 295 | 263 | 243 | |||||||||
Interest and dividend income | 12 | 7 | 2 | |||||||||
Interest Expense | 131 | 112 | 143 | |||||||||
Income taxes (benefit) | 127 | 143 | 110 | |||||||||
Net income (loss) attributable to Ameren common shareholders | 214 | 201 | 160 | |||||||||
Capital expenditures | 918 | 835 | 701 | |||||||||
TOTAL ASSETS | [1] | 8,903 | 8,204 | 8,903 | 8,204 | 7,397 | ||||||
Other Segment | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
External revenues | 70 | 31 | 15 | |||||||||
Revenue from Related Parties | 2 | 2 | 2 | |||||||||
Depreciation and amortization | 9 | 9 | 9 | |||||||||
Interest and dividend income | 1 | 2 | 1 | |||||||||
Interest Expense | 5 | 18 | 45 | |||||||||
Income taxes (benefit) | 27 | 5 | (41) | |||||||||
Net income (loss) attributable to Ameren common shareholders | 13 | (4) | (43) | |||||||||
Capital expenditures | [2] | 377 | 203 | 30 | ||||||||
TOTAL ASSETS | [1] | 1,139 | 799 | 1,139 | 799 | 711 | ||||||
Intersegment Elimination | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
External revenues | 0 | 0 | 0 | |||||||||
Revenue from Related Parties | (49) | (31) | (31) | |||||||||
Depreciation and amortization | 0 | 0 | 0 | |||||||||
Interest and dividend income | 0 | 0 | 0 | |||||||||
Interest Expense | 0 | 0 | 0 | |||||||||
Income taxes (benefit) | 0 | 0 | 0 | |||||||||
Net income (loss) attributable to Ameren common shareholders | 0 | 0 | 0 | |||||||||
Capital expenditures | 0 | 0 | 0 | |||||||||
TOTAL ASSETS | (267) | (203) | (267) | (203) | (233) | |||||||
Segment, Continuing Operations | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
External revenues | 6,098 | 6,053 | 5,838 | |||||||||
Revenue from Related Parties | 0 | 0 | 0 | |||||||||
Depreciation and amortization | 796 | 745 | 706 | |||||||||
Interest and dividend income | 41 | 37 | 30 | |||||||||
Interest Expense | 355 | 341 | 398 | |||||||||
Income taxes (benefit) | 363 | 377 | 311 | |||||||||
Capital expenditures | 1,917 | 1,785 | 1,379 | |||||||||
TOTAL ASSETS | [1],[3] | $ 23,626 | $ 22,274 | $ 23,626 | $ 22,274 | $ 20,742 | ||||||
[1] | (c)Reflects the adoption of the new authoritative accounting guidance for the presentation of debt issuance costs and balance sheet classification of deferred income taxes. See Note 1 – Summary of Significant Accounting Policies for additional information. | |||||||||||
[2] | (a)Includes the elimination of intercompany transfers. | |||||||||||
[3] | (b)Excludes total assets from discontinued operations of $14 million, $15 million, and $165 million as of December 31, 2015, 2014, and 2013, respectively. |
Selected Quarterly Informati122
Selected Quarterly Information (Summary Of Selected Quarterly Information) (Details) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2015 | Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating revenues | $ 1,308 | $ 1,833 | $ 1,401 | $ 1,556 | $ 1,370 | $ 1,670 | $ 1,419 | $ 1,594 | $ 6,098 | $ 6,053 | $ 5,838 |
Operating Income | 140 | 626 | 237 | 256 | 125 | 561 | 322 | 246 | 1,259 | 1,254 | 1,184 |
Net income | 30 | 345 | 151 | 110 | 49 | 295 | 150 | 98 | 636 | 592 | 295 |
Net income attributable to Ameren common shareholders - continuing operations | 30 | 343 | 98 | 108 | 46 | 294 | 150 | 97 | 579 | 587 | 512 |
Net Income (Loss) Attributable to Ameren common shareholders- Discontinued Operations | (1) | 0 | 52 | 0 | 2 | (1) | (1) | (1) | 51 | (1) | (223) |
Net income attributable to Ameren common shareholders | $ 29 | $ 343 | $ 150 | $ 108 | $ 48 | $ 293 | $ 149 | $ 96 | $ 630 | $ 586 | $ 289 |
Earnings per common share - basic - continuing operations | $ 0.12 | $ 1.42 | $ 0.40 | $ 0.45 | $ 0.19 | $ 1.21 | $ 0.62 | $ 0.40 | $ 2.39 | $ 2.42 | $ 2.11 |
Earnings (loss) per common share - basic - discontinued operations | 0 | 0 | 0.21 | 0 | 0.01 | 0 | (0.01) | 0 | 0.21 | 0 | (0.92) |
Earnings per common share - basic | 0.12 | 1.42 | 0.61 | 0.45 | 0.20 | 1.21 | 0.61 | 0.40 | 2.60 | 2.42 | 1.19 |
Earnings per common share - diluted - continuing operations | 0.12 | 1.41 | 0.40 | 0.45 | 0.19 | 1.20 | 0.62 | 0.40 | 2.38 | 2.40 | 2.10 |
Earnings (loss) per common share - diluted - discontinued operations | 0 | 0 | 0.21 | 0 | 0.01 | 0 | (0.01) | 0 | 0.21 | 0 | (0.92) |
Earnings per common share - diluted | $ 0.12 | $ 1.41 | $ 0.61 | $ 0.45 | $ 0.20 | $ 1.20 | $ 0.61 | $ 0.40 | $ 2.59 | $ 2.40 | $ 1.18 |
Union Electric Company | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating revenues | $ 754 | $ 1,171 | $ 884 | $ 800 | $ 739 | $ 1,097 | $ 900 | $ 817 | $ 3,609 | $ 3,553 | $ 3,541 |
Operating Income | 58 | 423 | 146 | 115 | 29 | 394 | 243 | 119 | 742 | 785 | 803 |
Net income | 355 | 393 | 398 | ||||||||
Net income attributable to Ameren common shareholders | 11 | 240 | 62 | 42 | (5) | 223 | 127 | 48 | 355 | 393 | 398 |
Net Income (Loss) Available to Common Shareholder | 11 | 239 | 61 | 41 | (5) | 222 | 126 | 47 | 352 | 390 | 395 |
Ameren Illinois Company | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating revenues | 553 | 655 | 513 | 745 | 633 | 572 | 519 | 774 | 2,466 | 2,498 | 2,311 |
Operating Income | 74 | 189 | 83 | 120 | 97 | 158 | 75 | 120 | 466 | 450 | 415 |
Net income | 217 | 204 | 163 | ||||||||
Net income attributable to Ameren common shareholders | 33 | 98 | 32 | 54 | 46 | 75 | 29 | 54 | 217 | 204 | 163 |
Net Income (Loss) Available to Common Shareholder | $ 32 | $ 98 | $ 31 | $ 53 | $ 45 | $ 75 | $ 28 | $ 53 | $ 214 | $ 201 | $ 160 |
Schedule I - Condensed Finan123
Schedule I - Condensed Financial Information Of Parent (Statement of Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||||||||
Dec. 31, 2015 | Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Condensed Financial Statements, Captions [Line Items] | ||||||||||||
Operating revenues | $ 1,308 | $ 1,833 | $ 1,401 | $ 1,556 | $ 1,370 | $ 1,670 | $ 1,419 | $ 1,594 | $ 6,098 | $ 6,053 | $ 5,838 | |
Operating expenses | 4,839 | 4,799 | 4,654 | |||||||||
Operating loss | 140 | 626 | 237 | 256 | 125 | 561 | 322 | 246 | 1,259 | 1,254 | 1,184 | |
Interest income from affiliates | [1],[2] | 14 | 10 | 3 | ||||||||
Other Nonoperating Income (Expense) | 44 | 57 | 43 | |||||||||
Interest charges | 355 | 341 | 398 | |||||||||
Income taxes (benefit) | 363 | 377 | 311 | |||||||||
Net income attributable to Ameren common shareholders - continuing operations | 30 | 343 | 98 | 108 | 46 | 294 | 150 | 97 | 579 | 587 | 512 | |
Net Income (Loss) Attributable to Ameren common shareholders- Discontinued Operations | (1) | 0 | 52 | 0 | 2 | (1) | (1) | (1) | 51 | (1) | (223) | |
Net income attributable to Ameren common shareholders | $ 29 | $ 343 | $ 150 | $ 108 | $ 48 | $ 293 | $ 149 | $ 96 | 630 | 586 | 289 | |
Comprehensive Income from Continuing Operations | ||||||||||||
Pension and other postretirement activity, net of income taxes (benefit) | 6 | (12) | 30 | |||||||||
Comprehensive Income from Continuing Operations Attributable to Ameren Common Shareholders | 585 | 575 | 542 | |||||||||
Other Comprehensive Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest | 0 | (18) | ||||||||||
Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Common shareholders | 51 | (1) | (242) | |||||||||
Comprehensive Income (Loss) Attributable to Ameren Common Shareholders | 636 | 574 | 300 | |||||||||
Other Comprehensive Income (Loss), Taxes: | ||||||||||||
Pension and other postretirement activity, tax (benefit) | 3 | (7) | 16 | |||||||||
Parent Company | ||||||||||||
Condensed Financial Statements, Captions [Line Items] | ||||||||||||
Operating expenses | 14 | 11 | 26 | |||||||||
Operating loss | (14) | (11) | (26) | |||||||||
Equity in earnings of subsidiaries | 600 | 607 | 546 | |||||||||
Interest income from affiliates | 6 | 3 | 3 | |||||||||
Other Nonoperating Income (Expense) | (5) | 2 | (5) | |||||||||
Interest charges | 3 | 16 | 42 | |||||||||
Income taxes (benefit) | 5 | (2) | (36) | |||||||||
Net income attributable to Ameren common shareholders - continuing operations | 579 | 587 | 512 | |||||||||
Net Income (Loss) Attributable to Ameren common shareholders- Discontinued Operations | 51 | (1) | (223) | |||||||||
Net income attributable to Ameren common shareholders | 630 | 586 | 289 | |||||||||
Comprehensive Income from Continuing Operations | ||||||||||||
Pension and other postretirement activity, net of income taxes (benefit) | 6 | (12) | 30 | |||||||||
Comprehensive Income from Continuing Operations Attributable to Ameren Common Shareholders | 585 | 575 | 542 | |||||||||
Other Comprehensive Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest | 0 | 0 | (19) | |||||||||
Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Common shareholders | 51 | (1) | (242) | |||||||||
Comprehensive Income (Loss) Attributable to Ameren Common Shareholders | 636 | 574 | 300 | |||||||||
Other Comprehensive Income (Loss), Taxes: | ||||||||||||
Pension and other postretirement activity, tax (benefit) | $ 3 | $ (7) | $ 16 | |||||||||
[1] | Includes Ameren Illinois' interest income on the IEIMA revenue requirement reconciliation adjustment regulatory assets. | |||||||||||
[2] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Schedule I - Condensed Finan124
Schedule I - Condensed Financial Information Of Parent (Balance Sheet) (Details) - USD ($) $ in Millions | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | Dec. 31, 2012 |
ASSETS | ||||
Cash and cash equivalents | $ 292 | $ 5 | $ 30 | $ 209 |
Miscellaneous accounts and notes receivable | 98 | 81 | ||
Other current assets | 88 | 86 | ||
Total current assets | 1,917 | 1,694 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 6 | 13 | ||
Other non-current assets | 575 | 629 | ||
TOTAL ASSETS | 23,640 | 22,289 | ||
LIABILITIES AND EQUITY | ||||
Short-term debt | 301 | 714 | ||
Other current liabilities | 379 | 434 | ||
Total current liabilities | 2,093 | 2,249 | ||
Long-term Debt, Net | 6,880 | 6,085 | ||
Pension and other postretirement benefits | 580 | 705 | ||
Other deferred credits and liabilities | $ 531 | $ 514 | ||
Commitments and Contingencies | ||||
Retained earnings | $ 1,331 | $ 1,103 | ||
Accumulated other comprehensive loss | (3) | (9) | ||
Total equity | 7,088 | 6,855 | 6,686 | |
TOTAL LIABILITIES AND EQUITY | 23,640 | 22,289 | ||
Parent Company | ||||
ASSETS | ||||
Cash and cash equivalents | 0 | 1 | $ 11 | $ 23 |
Advances to money pool | 0 | 55 | ||
Accounts receivable - affiliates | 53 | 28 | ||
Notes Receivable, Related Parties, Current | 0 | 94 | ||
Miscellaneous accounts and notes receivable | 3 | 39 | ||
Other current assets | 9 | 14 | ||
Total current assets | 65 | 231 | ||
Investments in subsidiaries - continuing operations | 7,231 | 6,680 | ||
Investments in subsidiaries - discontinued operations | (4) | (4) | ||
Note receivable - affiliates | 290 | 100 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 426 | 407 | ||
Other non-current assets | 158 | 152 | ||
TOTAL ASSETS | 8,166 | 7,566 | ||
LIABILITIES AND EQUITY | ||||
Short-term debt | 301 | 585 | ||
Borrowings from money pool | 14 | 0 | ||
Accounts payable – affiliates | 75 | 88 | ||
Other current liabilities | 22 | 52 | ||
Total current liabilities | 412 | 725 | ||
Long-term Debt, Net | 694 | 0 | ||
Pension and other postretirement benefits | 33 | 47 | ||
Other deferred credits and liabilities | 81 | 81 | ||
Total liabilities | 1,220 | 853 | ||
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 242.6 | 2 | 2 | ||
Other paid-in capital, principally premium on common stock | 5,616 | 5,617 | ||
Retained earnings | 1,331 | 1,103 | ||
Accumulated other comprehensive loss | (3) | (9) | ||
Total equity | 6,946 | 6,713 | ||
TOTAL LIABILITIES AND EQUITY | $ 8,166 | $ 7,566 |
Schedule I - Condensed Finan125
Schedule I - Condensed Financial Information Of Parent (Statement of Cash Flows) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Condensed Financial Statements, Captions [Line Items] | |||
Net cash provided by operating activities | $ 2,017 | $ 1,551 | $ 1,693 |
Cash Flows From Investing Activities: | |||
Proceeds from Collection of Notes Receivable | 20 | 95 | 6 |
Contributions to Note Receivable | (8) | (89) | (5) |
Other | 20 | 11 | 1 |
Net Cash Provided by (Used in) Investing Activities | (1,976) | (1,717) | (1,723) |
Cash flows from financing activities: | |||
Dividends on common stock | (402) | (390) | (388) |
Short-term debt, net | (413) | 346 | 368 |
Repayments of Other Long-term Debt | (120) | (697) | (399) |
Issuances of Long-term debt | 1,197 | 898 | 278 |
Capital issuance costs | (12) | (11) | (2) |
Other | 2 | 1 | 0 |
Net cash provided by (used in) financing activities | 246 | 141 | (149) |
Net change in cash and cash equivalents | 287 | (25) | (179) |
Cash and cash equivalents at beginning of year | 5 | 30 | 209 |
Cash and cash equivalents at end of year | 292 | 5 | 30 |
Parent Company | |||
Condensed Financial Statements, Captions [Line Items] | |||
Net cash provided by operating activities | 537 | 514 | 453 |
Cash Flows From Investing Activities: | |||
Money pool advances, net | 55 | 279 | (371) |
Intercompany notes receivable, net | (96) | (134) | (23) |
Investments in subsidiaries | (509) | (280) | (50) |
Return of investments | 0 | 215 | 1 |
Proceeds from Collection of Notes Receivable | 20 | 95 | 6 |
Contributions to Note Receivable | (8) | (89) | (5) |
Other | (24) | (12) | (3) |
Net Cash Provided by (Used in) Investing Activities | (562) | 74 | (445) |
Cash flows from financing activities: | |||
Dividends on common stock | (402) | (390) | (388) |
Short-term debt, net | (284) | 217 | 368 |
Money pool borrowings, net | 14 | 0 | 0 |
Repayments of Other Long-term Debt | 0 | (425) | 0 |
Issuances of Long-term debt | 700 | 0 | 0 |
Capital issuance costs | (6) | 0 | 0 |
Other | 2 | 0 | 0 |
Net cash provided by (used in) financing activities | 24 | (598) | (20) |
Net change in cash and cash equivalents | (1) | (10) | (12) |
Cash and cash equivalents at beginning of year | 1 | 11 | 23 |
Cash and cash equivalents at end of year | 0 | 1 | 11 |
Cash dividends received from consolidated subsidiaries | 575 | 340 | 570 |
Noncash investing activity - divestiture | 0 | 0 | 494 |
Noncash Investing activity- investment in subsidiaries | $ (38) | $ (19) | $ 0 |
Schedule I - Condensed Finan126
Schedule I - Condensed Financial Information Of Parent (Impairment and Other Charges) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 12 Months Ended | ||
May. 31, 2014 | Dec. 31, 2015 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | |
Impairment and Other Charges [Line Items] | |||||
Deferred Income Taxes and Other Assets, Current | $ 352 | ||||
Repayments of Other Long-term Debt | $ 120 | 697 | $ 399 | ||
Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Deferred Income Taxes and Other Assets, Current | 143 | ||||
Guarantees Outstanding | $ 36 | 36 | |||
Repayments of Other Long-term Debt | 0 | 425 | 0 | ||
Parent Company | Merchant Generation | |||||
Impairment and Other Charges [Line Items] | |||||
Impairment charge on long-lived assets and related charges | $ 201 | ||||
New Ameren Energy Resources Company, LLC | |||||
Impairment and Other Charges [Line Items] | |||||
Loss Contingency Accrual | 25 | 25 | |||
New Ameren Energy Resources Company, LLC | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Loss Contingency Accrual | $ 25 | $ 25 | |||
Senior Unsecured Notes8875 Due2014 [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Repayments of Other Long-term Debt | $ 425 | ||||
Long-term debt interest rate | 8.875% | ||||
Senior Unsecured Notes270 due 2020 [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Long-term debt interest rate | 2.70% | 2.70% | |||
Senior Unsecured Notes365 due 2026 [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Long-term debt interest rate | 3.65% | 3.65% | |||
Unsecured Debt [Member] | Senior Unsecured Notes270 due 2020 [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Debt instrument face amount | $ 350 | $ 350 | 0 | ||
Proceeds from issuance of secured debt | $ 348 | ||||
Long-term debt interest rate | 2.70% | 2.70% | |||
Unsecured Debt [Member] | Senior Unsecured Notes365 due 2026 [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Debt instrument face amount | $ 350 | $ 350 | $ 0 | ||
Proceeds from issuance of secured debt | $ 347 | ||||
Long-term debt interest rate | 3.65% | 3.65% | |||
2013 Tax Year [Member] | Parent Company | |||||
Impairment and Other Charges [Line Items] | |||||
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | $ 53 |
Schedule II - Valuation And 127
Schedule II - Valuation And Qualifying Accounts (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 | ||
Allowance For Doubtful Accounts | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | $ 21 | $ 18 | $ 17 | |
Charged to Costs and Expenses | 33 | 36 | 35 | |
Charged to Other Accounts | [1] | 5 | 4 | 4 |
Deductions | [2] | 40 | 37 | 38 |
Balance at End of Period | 19 | 21 | 18 | |
Valuation Allowance of Deferred Tax Assets | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | 10 | 7 | 2 | |
Charged to Costs and Expenses | 4 | 3 | 5 | |
Charged to Other Accounts | [1] | (8) | 0 | 0 |
Deductions | 0 | 0 | 0 | |
Balance at End of Period | 6 | 10 | 7 | |
Union Electric Company | Allowance For Doubtful Accounts | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | 8 | 5 | 5 | |
Charged to Costs and Expenses | 13 | 16 | 16 | |
Charged to Other Accounts | [1] | 0 | 0 | 0 |
Deductions | [2] | 14 | 13 | 16 |
Balance at End of Period | 7 | 8 | 5 | |
Union Electric Company | Valuation Allowance of Deferred Tax Assets | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | 1 | 1 | 1 | |
Charged to Costs and Expenses | 0 | 0 | 0 | |
Charged to Other Accounts | [1] | (1) | 0 | 0 |
Deductions | 0 | 0 | 0 | |
Balance at End of Period | 0 | 1 | 1 | |
Ameren Illinois Company | Allowance For Doubtful Accounts | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | 13 | 13 | 12 | |
Charged to Costs and Expenses | 20 | 20 | 19 | |
Charged to Other Accounts | [1] | 5 | 4 | 4 |
Deductions | [2] | 26 | 24 | 22 |
Balance at End of Period | 12 | 13 | 13 | |
Ameren Illinois Company | Valuation Allowance of Deferred Tax Assets | ||||
Valuation and Qualifying Accounts Disclosure [Line Items] | ||||
Balance at Beginning of Period | 1 | 1 | 1 | |
Charged to Costs and Expenses | 0 | 0 | 0 | |
Charged to Other Accounts | [1] | (1) | 0 | 0 |
Deductions | 0 | 0 | 0 | |
Balance at End of Period | $ 0 | $ 1 | $ 1 | |
[1] | Amounts associated with the allowance for doubtful accounts relate to the uncollectible account reserve associated with receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. The amounts relating to the deferred tax valuation allowance are for items that have expired and were removed from both the underlying accumulated deferred income tax account as well as the offsetting valuation account. | |||
[2] | Uncollectible accounts charged off, less recoveries. |