Document and Entity Information
Document and Entity Information - shares | 6 Months Ended | |
Jun. 30, 2015 | Jul. 31, 2015 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q2 | |
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 | |
Union Electric Company | ||
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q2 | |
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 | |
Ameren Illinois Company | ||
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q2 | |
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 |
Consolidated Statement of Incom
Consolidated Statement of Income (Loss) - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
Operating Revenues: | |||||
Electric | $ 1,250 | $ 1,235 | $ 2,393 | $ 2,341 | |
Gas | 151 | 184 | 564 | 672 | |
Total operating revenues | 1,401 | 1,419 | 2,957 | 3,013 | |
Operating Expenses: | |||||
Fuel | 205 | 198 | 411 | 402 | |
Purchased power | 101 | 112 | 240 | 226 | |
Gas purchased for resale | 46 | 79 | 282 | 383 | |
Other operations and maintenance | 427 | 411 | 828 | 829 | |
Provision for Callaway construction and operating license | 69 | 0 | 69 | 0 | |
Depreciation and amortization | 200 | 183 | 393 | 364 | |
Taxes other than income taxes | 116 | 114 | 241 | 241 | |
Total operating expenses | 1,164 | 1,097 | 2,464 | 2,445 | |
Operating Income | 237 | 322 | 493 | 568 | |
Other Income and Expenses: | |||||
Miscellaneous income | [1] | 16 | 21 | 35 | 39 |
Miscellaneous expense | [1] | 6 | 4 | 17 | 13 |
Total other income (expense) | 10 | 17 | 18 | 26 | |
Interest Charges | 89 | 89 | 177 | 181 | |
Income Before Income Taxes | 158 | 250 | 334 | 413 | |
Income Taxes | 59 | 99 | 125 | 163 | |
Income from Continuing Operations | 99 | 151 | 209 | 250 | |
Income (Loss) from Discontinued Operations, Net of Taxes (Note 12) | 52 | (1) | 52 | (2) | |
Net Income (Loss) | 151 | 150 | 261 | 248 | |
Pension and other postretirement benefit plan activity, net of income taxes (benefit) | 4 | 3 | 4 | 3 | |
Comprehensive Income | 154 | 152 | 262 | 248 | |
Less: Net Income (Loss) Attributable to Noncontrolling Interests: | |||||
Net Income from Continuing Operations Attributable to Noncontrolling Interests | 1 | 1 | 3 | 3 | |
Net Income (Loss): | |||||
Continuing Operations | 98 | 150 | 206 | 247 | |
Discontinued Operations | 52 | (1) | 52 | (2) | |
Net Income (Loss) | $ 150 | $ 149 | $ 258 | $ 245 | |
Earnings Per Share, Basic [Abstract] | |||||
Continuing Operations | $ 0.40 | $ 0.62 | $ 0.85 | $ 1.02 | |
Discontinued Operations | 0.21 | (0.01) | 0.21 | (0.01) | |
Earnings Per Share, Basic | 0.61 | 0.61 | 1.06 | 1.01 | |
Dividends per Common Share | $ 0.41 | $ 0.40 | $ 0.82 | $ 0.80 | |
Average Common Shares Outstanding - Basic | 242.6 | 242.6 | 242.6 | 242.6 | |
Union Electric Company | |||||
Operating Revenues: | |||||
Electric | $ 859 | $ 871 | $ 1,601 | $ 1,620 | |
Gas | 24 | 28 | 82 | 96 | |
Other Revenue, Net | 1 | 1 | 1 | 1 | |
Total operating revenues | 884 | 900 | 1,684 | 1,717 | |
Operating Expenses: | |||||
Fuel | 205 | 198 | 411 | 402 | |
Purchased power | 19 | 29 | 58 | 64 | |
Gas purchased for resale | 7 | 11 | 38 | 51 | |
Other operations and maintenance | 229 | 221 | 440 | 446 | |
Provision for Callaway construction and operating license | 69 | 0 | 69 | 0 | |
Depreciation and amortization | 124 | 117 | 242 | 233 | |
Taxes other than income taxes | 85 | 81 | 165 | 159 | |
Total operating expenses | 738 | 657 | 1,423 | 1,355 | |
Operating Income | 146 | 243 | 261 | 362 | |
Other Income and Expenses: | |||||
Miscellaneous income | 12 | 16 | 23 | 30 | |
Miscellaneous expense | 2 | 2 | 5 | 6 | |
Total other income (expense) | 10 | 14 | 18 | 24 | |
Interest Charges | 55 | 54 | 110 | 106 | |
Income Before Income Taxes | 101 | 203 | 169 | 280 | |
Income Taxes | 39 | 76 | 65 | 105 | |
Net Income (Loss) | 62 | 127 | 104 | 175 | |
Other Comprehensive Income | 0 | 0 | 0 | 0 | |
Comprehensive Income | 62 | 127 | 104 | 175 | |
Net Income (Loss): | |||||
Net Income (Loss) | 62 | 127 | 104 | 175 | |
Earnings Per Share, Basic [Abstract] | |||||
Preferred Stock Dividends | 1 | 1 | 2 | 2 | |
Net Income Available to Common Stockholder | 61 | 126 | 102 | 173 | |
Ameren Illinois Company | |||||
Operating Revenues: | |||||
Electric | 386 | 364 | 776 | 717 | |
Gas | 127 | 155 | 482 | 576 | |
Total operating revenues | 513 | 519 | 1,258 | 1,293 | |
Operating Expenses: | |||||
Purchased power | 87 | 86 | 189 | 167 | |
Gas purchased for resale | 39 | 67 | 244 | 331 | |
Other operations and maintenance | 202 | 195 | 404 | 395 | |
Depreciation and amortization | 73 | 64 | 146 | 127 | |
Taxes other than income taxes | 29 | 32 | 72 | 78 | |
Total operating expenses | 430 | 444 | 1,055 | 1,098 | |
Operating Income | 83 | 75 | 203 | 195 | |
Other Income and Expenses: | |||||
Miscellaneous income | 4 | 5 | 11 | 8 | |
Miscellaneous expense | 2 | 1 | 7 | 5 | |
Total other income (expense) | 2 | 4 | 4 | 3 | |
Interest Charges | 33 | 29 | 66 | 59 | |
Income Before Income Taxes | 52 | 50 | 141 | 139 | |
Income Taxes | 20 | 21 | 55 | 56 | |
Net Income (Loss) | 32 | 29 | 86 | 83 | |
Pension and other postretirement benefit plan activity, net of income taxes (benefit) | (1) | (1) | (2) | (2) | |
Comprehensive Income | 31 | 28 | 84 | 81 | |
Net Income (Loss): | |||||
Net Income (Loss) | 32 | 29 | 86 | 83 | |
Earnings Per Share, Basic [Abstract] | |||||
Preferred Stock Dividends | 1 | 1 | 2 | 2 | |
Net Income Available to Common Stockholder | $ 31 | $ 28 | $ 84 | $ 81 | |
[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 | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Pension and other postretirement benefit plan activity, tax expense (benefit) | $ 4 | $ 3 | $ 4 | $ 3 |
Ameren Illinois Company | ||||
Pension and other postretirement benefit plan activity, tax expense (benefit) | $ 0 | $ 0 | $ (1) | $ (1) |
Consolidated Statement of Compr
Consolidated Statement of Comprehensive Income (Loss) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Statement of Comprehensive Income [Abstract] | ||||
Income from Continuing Operations | $ 99 | $ 151 | $ 209 | $ 250 |
Other Comprehensive Income from Continuing Operations, Net Of Taxes | ||||
Other Comprehensive Income from Continuing Operations, Net of Taxes | ||||
Pension and other postretirement benefit plan activity, net of income taxes (benefit) | 4 | 3 | $ 4 | $ 3 |
Comprehensive Income from Continuing Operations | 103 | 154 | 213 | 253 |
Less: Comprehensive Income from Continuing Operations Attributable to Noncontrolling Interests | 1 | 1 | 3 | 3 |
Comprehensive Income from Continuing Operations Attributable to Ameren Corporation | 102 | 153 | 210 | 250 |
Income (Loss) from Discontinued Operations, Net of Taxes | 52 | (1) | 52 | (2) |
Other Comprehensive Loss from Discontinued Operations, Net of Taxes | 0 | 0 | 0 | 0 |
Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Corporation | 52 | (1) | 52 | (2) |
Comprehensive Income | $ 154 | $ 152 | $ 262 | $ 248 |
Consolidated Statement of Comp5
Consolidated Statement of Comprehensive Income (Loss) Consolidated Statement of Income (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Statement of Comprehensive Income [Abstract] | ||||
Pension and other postretirement benefit plan activity, tax expense (benefit) | $ 4 | $ 3 | $ 4 | $ 3 |
Consolidated Balance Sheet
Consolidated Balance Sheet - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Current Assets: | ||
Cash and cash equivalents | $ 2 | $ 5 |
Accounts receivable - trade (less allowance for doubtful accounts) | 456 | 423 |
Unbilled revenue | 302 | 265 |
Miscellaneous accounts and notes receivable | 112 | 81 |
Materials and supplies | 500 | 524 |
Current regulatory assets | 223 | 295 |
Current accumulated deferred income taxes, net | 286 | 352 |
Other current assets | 95 | 86 |
Assets of discontinued operations (Note 12) | 15 | 15 |
Total current assets | 1,991 | 2,046 |
Property and Plant, Net | 17,986 | 17,424 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 555 | 549 |
Goodwill | 411 | 411 |
Regulatory assets | 1,560 | 1,582 |
Other assets | 649 | 664 |
Total investments and other assets | 3,175 | 3,206 |
TOTAL ASSETS | 23,152 | 22,676 |
Current Liabilities: | ||
Current maturities of long-term debt | 395 | 120 |
Short-term Debt | 886 | 714 |
Accounts and wages payable | 486 | 711 |
Taxes accrued | 126 | 46 |
Interest accrued | 98 | 85 |
Current regulatory liabilities | 120 | 106 |
Other current liabilities | 413 | 434 |
Liabilities of discontinued operations (Note 12) | 32 | 33 |
Total current liabilities | 2,556 | 2,249 |
Long-term Debt, Net | 5,981 | 6,120 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes, net | 3,931 | 3,923 |
Accumulated deferred investment tax credits | 64 | 64 |
Regulatory liabilities | 1,912 | 1,850 |
Asset retirement obligations | 589 | 396 |
Pension and other postretirement benefits | 689 | 705 |
Other deferred credits and liabilities | 524 | 514 |
Total deferred credits and other liabilities | $ 7,709 | $ 7,452 |
Commitments and Contingencies | ||
Stockholders' Equity: | ||
Common Stock | $ 2 | $ 2 |
Other paid-in capital | 5,606 | 5,617 |
Retained earnings | 1,161 | 1,103 |
Accumulated other comprehensive income (loss) | (5) | (9) |
Stockholder's equity | 6,764 | 6,713 |
Noncontrolling Interest | 142 | 142 |
Total equity | 6,906 | 6,855 |
TOTAL LIABILITIES AND EQUITY | 23,152 | 22,676 |
Union Electric Company | ||
Current Assets: | ||
Cash and cash equivalents | 0 | 1 |
Accounts receivable - trade (less allowance for doubtful accounts) | 227 | 190 |
Accounts receivable - affiliates | 13 | 65 |
Unbilled revenue | 213 | 146 |
Miscellaneous accounts and notes receivable | 54 | 35 |
Materials and supplies | 371 | 347 |
Current regulatory assets | 133 | 163 |
Other current assets | 89 | 92 |
Total current assets | 1,100 | 1,039 |
Property and Plant, Net | 11,017 | 10,867 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 555 | 549 |
Regulatory assets | 660 | 695 |
Other assets | 389 | 391 |
Total investments and other assets | 1,604 | 1,635 |
TOTAL ASSETS | 13,721 | 13,541 |
Current Liabilities: | ||
Current maturities of long-term debt | 266 | 120 |
Short-term Debt | 38 | 97 |
Accounts and wages payable | 183 | 405 |
Accounts payable - affiliates | 43 | 56 |
Taxes accrued | 151 | 32 |
Interest accrued | 73 | 58 |
Current regulatory liabilities | 58 | 18 |
Other current liabilities | 124 | 117 |
Total current liabilities | 936 | 903 |
Long-term Debt, Net | 3,869 | 3,879 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes, net | 2,826 | 2,806 |
Accumulated deferred investment tax credits | 61 | 61 |
Regulatory liabilities | 1,188 | 1,147 |
Asset retirement obligations | 582 | 389 |
Pension and other postretirement benefits | 275 | 274 |
Other deferred credits and liabilities | 30 | 30 |
Total deferred credits and other liabilities | $ 4,962 | $ 4,707 |
Commitments and Contingencies | ||
Stockholders' Equity: | ||
Common Stock | $ 511 | $ 511 |
Other paid-in capital | 1,784 | 1,569 |
Preferred stock | 80 | 80 |
Retained earnings | 1,579 | 1,892 |
Stockholder's equity | 3,954 | 4,052 |
TOTAL LIABILITIES AND EQUITY | 13,721 | 13,541 |
Ameren Illinois Company | ||
Current Assets: | ||
Cash and cash equivalents | 0 | 1 |
Accounts receivable - trade (less allowance for doubtful accounts) | 207 | 212 |
Accounts receivable - affiliates | 8 | 22 |
Unbilled revenue | 89 | 119 |
Miscellaneous accounts and notes receivable | 11 | 9 |
Materials and supplies | 129 | 177 |
Current regulatory assets | 89 | 129 |
Current accumulated deferred income taxes, net | 159 | 160 |
Other current assets | 10 | 15 |
Total current assets | 702 | 844 |
Property and Plant, Net | 6,416 | 6,165 |
Investments and Other Assets: | ||
Goodwill | 411 | 411 |
Regulatory assets | 893 | 883 |
Other assets | 78 | 78 |
Total investments and other assets | 1,382 | 1,372 |
TOTAL ASSETS | 8,500 | 8,381 |
Current Liabilities: | ||
Current maturities of long-term debt | 129 | 0 |
Short-term Debt | 12 | 32 |
Borrowings from money pool | 25 | 15 |
Accounts and wages payable | 229 | 207 |
Accounts payable - affiliates | 43 | 50 |
Taxes accrued | 10 | 17 |
Interest accrued | 25 | 24 |
Customer deposits | 73 | 77 |
Mark-to-market derivative liabilities | 35 | 42 |
Current environmental remediation | 43 | 52 |
Current regulatory liabilities | 53 | 84 |
Other current liabilities | 80 | 100 |
Total current liabilities | 757 | 700 |
Long-term Debt, Net | 2,112 | 2,241 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes, net | 1,454 | 1,408 |
Regulatory liabilities | 724 | 703 |
Pension and other postretirement benefits | 292 | 277 |
Environmental remediation | 198 | 199 |
Other deferred credits and liabilities | 221 | 192 |
Total deferred credits and other liabilities | $ 2,889 | $ 2,779 |
Commitments and Contingencies | ||
Stockholders' Equity: | ||
Common Stock | $ 0 | $ 0 |
Other paid-in capital | 1,980 | 1,980 |
Preferred stock | 62 | 62 |
Retained earnings | 694 | 611 |
Accumulated other comprehensive income (loss) | 6 | 8 |
Stockholder's equity | 2,742 | 2,661 |
TOTAL LIABILITIES AND EQUITY | $ 8,500 | $ 8,381 |
Consolidated Balance Sheet (Par
Consolidated Balance Sheet (Parenthetical) - USD ($) shares in Millions, $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Accounts receivable - trade allowance for doubtful accounts | $ 21 | $ 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 | $ 13 | $ 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 | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Cash Flows From Operating Activities: | |||
Net income (loss) | $ 261 | $ 248 | |
(Income) loss from discontinued operations, net of taxes | (52) | 2 | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||
Provision for Callaway construction and operating license | 69 | 0 | |
Depreciation and amortization | 387 | 349 | |
Amortization of nuclear fuel | 47 | 47 | |
Amortization of debt issuance costs and premium/discounts | 11 | 11 | |
Deferred income taxes and investment tax credits, net | 116 | 178 | |
Allowance for equity funds used during construction | [1] | (11) | (16) |
Stock-based compensation costs | 14 | 15 | |
Other | (13) | (8) | |
Changes in assets and liabilities: | |||
Receivables | (80) | (62) | |
Materials and supplies | 25 | 35 | |
Accounts and wages payable | (180) | (180) | |
Taxes accrued | 81 | 68 | |
Regulatory assets and liabilities | 65 | (98) | |
Assets, other | 25 | 54 | |
Liabilities, other | (27) | (21) | |
Pension and other postretirement benefits | 28 | 21 | |
Counterparty collateral, net | 2 | 15 | |
Net cash provided by operating activities ā continuing operations | 768 | 658 | |
Net cash used in operating activities ā discontinued operations | (1) | (4) | |
Net cash provided by operating activities | 767 | 654 | |
Cash Flows From Investing Activities: | |||
Capital expenditures | (846) | (883) | |
Nuclear fuel expenditures | (28) | (26) | |
Purchases of securities - nuclear decommissioning trust fund | (117) | (290) | |
Sales and maturities of securities - nuclear decommissioning trust fund | 110 | 283 | |
Proceeds from Notes Receivable | 10 | 70 | |
Contributions to Note Receivable | (7) | (78) | |
Other | 3 | 2 | |
Net cash used in investing activities ā continuing operations | (875) | (922) | |
Net cash provided by investing activities ā discontinued operations | 0 | 152 | |
Net cash used in investing activities | (875) | (770) | |
Cash Flows From Financing Activities: | |||
Dividends on common stock | (199) | (194) | |
Dividends paid to noncontrolling interest holders | (3) | (3) | |
Short-term debt, net | 172 | 425 | |
Redemptions of Long-term Debt | (114) | (692) | |
Issuances of Long-term Debt | 249 | 598 | |
Capital issuance costs | (2) | (4) | |
Other | 2 | 2 | |
Net cash provided by (used in) financing activities ā continuing operations | 105 | 132 | |
Net cash used in financing activities - discontinued operations | 0 | 0 | |
Net cash provided by financing activities | 105 | 132 | |
Net change in cash and cash equivalents | (3) | 16 | |
Cash and cash equivalents at beginning of period | 5 | 30 | |
Cash and cash equivalents at end of period | 2 | 46 | |
Union Electric Company | |||
Cash Flows From Operating Activities: | |||
Net income (loss) | 104 | 175 | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||
Provision for Callaway construction and operating license | 69 | 0 | |
Depreciation and amortization | 238 | 220 | |
Amortization of nuclear fuel | 47 | 47 | |
Amortization of debt issuance costs and premium/discounts | 3 | 4 | |
Deferred income taxes and investment tax credits, net | 27 | 61 | |
Allowance for equity funds used during construction | (9) | (15) | |
Changes in assets and liabilities: | |||
Receivables | (80) | (97) | |
Materials and supplies | (24) | 0 | |
Accounts and wages payable | (180) | (163) | |
Taxes accrued | 123 | (65) | |
Regulatory assets and liabilities | 63 | (49) | |
Assets, other | 16 | 43 | |
Liabilities, other | 35 | 40 | |
Pension and other postretirement benefits | 14 | 11 | |
Net cash provided by operating activities | 446 | 212 | |
Cash Flows From Investing Activities: | |||
Capital expenditures | (289) | (375) | |
Nuclear fuel expenditures | (28) | (26) | |
Purchases of securities - nuclear decommissioning trust fund | (117) | (290) | |
Sales and maturities of securities - nuclear decommissioning trust fund | 110 | 283 | |
Other | (4) | (5) | |
Net cash used in investing activities | (328) | (413) | |
Cash Flows From Financing Activities: | |||
Dividends on common stock | (415) | (155) | |
Dividends on preferred stock | (2) | (2) | |
Short-term debt, net | (59) | 185 | |
Money pool borrowings, net | 0 | (44) | |
Redemptions of Long-term Debt | (114) | (104) | |
Issuances of Long-term Debt | 249 | 350 | |
Capital contribution from parent | 224 | 0 | |
Capital issuance costs | (2) | (2) | |
Net cash provided by financing activities | (119) | 228 | |
Net change in cash and cash equivalents | (1) | 27 | |
Cash and cash equivalents at beginning of period | 1 | 1 | |
Cash and cash equivalents at end of period | 0 | 28 | |
Ameren Illinois Company | |||
Cash Flows From Operating Activities: | |||
Net income (loss) | 86 | 83 | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||
Depreciation and amortization | 144 | 125 | |
Amortization of debt issuance costs and premium/discounts | 7 | 6 | |
Deferred income taxes and investment tax credits, net | 45 | 58 | |
Allowance for equity funds used during construction | (2) | (1) | |
Other | (5) | (4) | |
Changes in assets and liabilities: | |||
Receivables | 57 | 36 | |
Materials and supplies | 48 | 36 | |
Accounts and wages payable | 20 | 2 | |
Taxes accrued | (6) | (5) | |
Regulatory assets and liabilities | (1) | (46) | |
Assets, other | 8 | 10 | |
Liabilities, other | (29) | (22) | |
Pension and other postretirement benefits | 12 | 7 | |
Counterparty collateral, net | 0 | 15 | |
Net cash provided by operating activities | 386 | 301 | |
Cash Flows From Investing Activities: | |||
Capital expenditures | (379) | (436) | |
Other | 4 | 4 | |
Net cash used in investing activities | (375) | (432) | |
Cash Flows From Financing Activities: | |||
Dividends on preferred stock | (2) | (2) | |
Short-term debt, net | (20) | 105 | |
Money pool borrowings, net | 10 | (56) | |
Redemptions of Long-term Debt | 0 | (163) | |
Issuances of Long-term Debt | 0 | 248 | |
Capital issuance costs | 0 | (2) | |
Proceeds from Advances for Construction | 0 | 2 | |
Net cash provided by financing activities | (12) | 132 | |
Net change in cash and cash equivalents | (1) | 1 | |
Cash and cash equivalents at beginning of period | 1 | 1 | |
Cash and cash equivalents at end of period | $ 0 | $ 2 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 6 Months Ended |
Jun. 30, 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, administered by the FERC. Amerenās primary assets are its equity interests in its subsidiaries, including Ameren Missouri and Ameren Illinois. Amerenās subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Amerenās common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Amerenās principal subsidiaries are listed below. Also see the Glossary of Terms and Abbreviations at the front of this report and in the Form 10-K. ā¢ 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. ā¢ Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric and natural gas transmission and distribution businesses in Illinois. 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. The operating results, assets, and liabilities of the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers have been presented separately as discontinued operations for all periods presented in this report. Unless otherwise stated, these notes to Amerenās financial statements exclude discontinued operations for all periods presented. See Note 12 - Divestiture Transactions and Discontinued Operations in this report for additional information regarding the discontinued operations presentation and Note 16 - Divestiture Transactions and Discontinued Operations under Part II, Item 8, of the Form 10-K for additional information regarding Amerenās divestiture of New AER in December 2013. Amerenās financial statements are prepared on a consolidated basis, and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Missouri and Ameren Illinois have no subsidiaries, and therefore their financial statements are not prepared on a consolidated basis. 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. The results of operations of an interim period may not give a true indication of results that may be expected for a full year. These financial statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Asset Retirement Obligations The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the six months ended June 30, 2015 : Ameren Missouri Ameren Illinois (a) Ameren Balance at December 31, 2014 $ 389 $ 7 $ 396 Accretion in 2015 (b) 11 (c) 11 Change in estimates (d) 182 (c) 182 Balance at June 30, 2015 $ 582 $ 7 $ 589 (a) Included in āOther deferred credits and liabilitiesā on the balance sheet. (b) Accretion expense was recorded as an increase to regulatory assets. (c) Less than $1 million. (d) The ARO increase resulted in a corresponding increase recorded to āProperty and Plant, Net.ā During the first quarter of 2015, 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, 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, during the second quarter of 2015, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $79 million to their AROs associated with CCR storage facilities. See Note 9 - Commitments and Contingencies for additional information. Also during the second quarter of 2015, Ameren and Ameren Missouri 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 MoPSCās April 2015 electric rate order. Stock-based Compensation A summary of nonvested performance share units at June 30, 2015 , and changes during the six months ended June 30, 2015 , under the 2006 Incentive Plan and the 2014 Incentive Plan are presented below: Number of Performance Share Units Weighted-average Fair Value Per Performance Share Unit Nonvested at January 1, 2015 1,162,377 $ 35.35 Granted (a) 567,240 52.88 Forfeitures (1,944 ) 34.75 Vested (b) (85,694 ) 46.79 Nonvested at June 30, 2015 1,641,979 $ 40.81 (a) Performance share units granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. (b) Performance share units vested due to the 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. The fair value of each performance share unit awarded in 2015 under the 2014 Incentive Plan was determined to be $52.88 , which was based on Amerenās 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 Amerenās total stockholder 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 performance 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 Amerenās attainment of a three-year average earnings per share threshold during the performance period. Excise Taxes Ameren Missouri and Ameren Illinois collect certain excise taxes from customers that are levied on the sale or distribution of natural gas and electricity. Excise taxes are levied on Ameren Missouriās electric and natural gas businesses and on Ameren Illinoisā natural gas business and are recorded gross in āOperating Revenues - Electric,ā āOperating Revenues - Gasā and āOperating Expenses - Taxes other than income taxesā on the statement of income or the statement of income and comprehensive income. Excise taxes for electric service in Illinois are levied on the customer and are therefore not included in Ameren Illinoisā revenues and expenses. The following table presents excise taxes recorded in āOperating Revenues - Electric,ā āOperating Revenues - Gasā and āOperating Expenses - Taxes other than income taxesā for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Ameren Missouri $ 41 $ 39 $ 75 $ 73 Ameren Illinois 10 11 33 37 Ameren $ 51 $ 50 $ 108 $ 110 Uncertain Tax Positions The following table presents the total amount of reserves for unrecognized tax benefits (detriments) related to uncertain tax positions as of June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Ameren $ ā $ 54 Ameren Missouri ā ā Ameren Illinois ā (1 ) The following table presents the amount of reserves for unrecognized tax benefits, included in the table above, related to uncertain tax positions that, if recognized, would have impacted results of operations as of December 31, 2014 : December 31, 2014 Ameren $ 52 Ameren Missouri ā Ameren Illinois (1 ) In March 2015, a settlement was reached with the IRS for the 2012 tax year. Since there were no uncertain tax positions related to the 2012 tax year, as of December 31, 2014, this settlement did not impact the amount of recorded unrecognized tax benefits. In June 2015, a settlement was reached with the IRS for the 2013 tax year. This settlement 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 Amerenās unrecognized tax benefits of $53 million and an increase to net income from discontinued operations. It is reasonably possible that events will occur during the next 12 months that would cause the total amount of our unrecognized tax benefits to fluctuate. We do not believe any such fluctuations would be material to our results of operations, financial position, or liquidity. State income tax returns are generally subject to examination for a period of three years after filing. We do not currently have material state income tax issues under examination, administrative appeal, or litigation. The state impact of any federal changes remains subject to examination by various states for a period of up to one year after formal notification to the states. Earnings Per Share There were no material differences between Amerenās basic and diluted earnings per share amounts for the three and six months ended June 30, 2015 and 2014 . The assumed settlement of dilutive performance share units had an immaterial impact on earnings per share. Accounting and Reporting Developments Below is a summary of recently issued authoritative accounting standards relevant to the Ameren Companies. Revenue from Contracts with Customers In 2014, FASB issued authoritative accounting guidance to clarify the principles for recognizing revenue and to develop a common revenue standard for GAAP. The guidance requires an entity to recognize an amount of revenue for the transfer of promised goods or services to customers that reflects the consideration which 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. In July 2015, FASB deferred the effective date of the new revenue standard to the first quarter of 2018. The guidance allows entities to choose one of two transition methods, either by applying the guidance retrospectively to each reporting period presented or 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 positions and disclosures, as well as the transition method that they will use to adopt the guidance. Presentation of Debt Issuance Costs In April 2015, FASB issued authoritative accounting guidance to simplify the presentation of debt issuance costs. The guidance requires debt issuance costs to be presented in the balance sheet as a reduction to the associated debt liability. Currently, debt issuance costs are presented as a component of āOther assetsā on the Ameren Companiesā balance sheets. As of June 30, 2015, Ameren, Ameren Missouri, and Ameren Illinois had debt issuance costs of $36 million , $20 million , and $16 million , respectively. The guidance will be effective for the Ameren Companies in the first quarter of 2016 and applied retrospectively, and it will not affect the Ameren Companies' results of operations or cash flows. |
Rate And Regulatory Matters
Rate And Regulatory Matters | 6 Months Ended |
Jun. 30, 2015 | |
Public Utilities, General Disclosures [Abstract] | |
RATE AND REGULATORY MATTERS | RATE AND REGULATORY MATTERS Below is a summary of updates to significant regulatory proceedings and related lawsuits. See also Note 2 - Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K. 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 impact on our results of operations, financial position, or liquidity. Missouri 2015 Electric Rate Order In April 2015, the MoPSC issued an order approving an increase in Ameren Missouriās annual revenues for electric service of $122 million , including $109 million related to the increase in net energy costs above those included in base rates previously authorized by the MoPSC. The remaining increase of $13 million approved by the order was for non-energy costs. 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 Missouriās request for continued use of the FAC; however, it changed the FAC to exclude all transmission revenues and substantially all transmission charges. In addition, the order did not approve the continued use of the regulatory tracking mechanisms for storm costs and vegetation management and infrastructure inspection costs. These changes to Ameren Missouriās 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 earlier electric rate orders. In addition, the order approved a reduction to Norandaās electric rates with an offsetting increase in electric rates for Ameren Missouriās other customers. The rate shift is revenue neutral to Ameren Missouri. In June 2015, Ameren Missouri filed a notice of appeal with the Missouri Court of Appeals, Western District, reserving the right to appeal the exclusion of all transmission revenues and substantially all transmission charges from the FAC, the reduction to Norandaās electric rates, and the level of Norandaās sales volume included in the MoPSCās order. MEEIA Filing The MEEIA established a regulatory framework that, among other things, requires the MoPSC to ensure that a utilityās 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 standards. In August 2012, the MoPSC approved Ameren Missouriās customer energy efficiency programs, net shared benefits, and performance incentive for 2013 through 2015. The 2013 through 2015 plan anticipated Ameren Missouri would invest up to $147 million in customer energy efficiency programs, realize $100 million of net shared benefits, and be eligible for a performance incentive that would allow Ameren Missouri the potential to earn additional revenues by achieving certain customer energy efficiency goals, including $19 million if 100% of the goals are achieved during the three-year period. From January 2013 through June 2015, Ameren Missouri invested $95 million in customer energy efficiency programs and realized $115 million of net shared benefits. Ameren Missouri has not recorded revenues associated with the performance incentive, but does expect to exceed 100% of the customer energy efficiency goals by the end of 2015, subject to MoPSC review, and therefore expects to recognize revenues in excess of $19 million within the next two years. In December 2014, Ameren Missouri filed a three-year energy efficiency plan with the MoPSC under the MEEIA for 2016 to 2018 that included a portfolio of customer energy efficiency programs along with a rider to collect the program costs, net shared benefits, and a performance incentive from customers. Ameren Missouri amended this proposed plan in June 2015 when it filed a non-unanimous stipulation and agreement with certain intervenor parties. If this plan is approved by the MoPSC, beginning in January 2016, Ameren Missouri intends to invest up to $197 million over three years in the proposed customer energy efficiency programs. Ameren Missouri requested continued use of a MEEIA rider, which allows Ameren Missouri to collect from, or refund to, customers any difference in the actual amounts incurred and the amounts collected from customers for the MEEIA program costs and net shared benefits. Ameren Missouri anticipates net shared benefits would be approximately $65 million during this three -year plan. In addition, similar to its existing MEEIA energy efficiency plan that ends in December 2015, Ameren Missouri requested a performance incentive that would allow it to potentially earn additional revenues by achieving certain customer energy efficiency goals, including $30 million if 100% of the goals are achieved during the three -year period. Ameren Missouri would need to achieve at least 70% of its customer energy efficiency goals before it earns a performance incentive. In July 2015, the MoPSC staff and certain intervenor parties filed a non-unanimous stipulation and agreement that is unacceptable to Ameren Missouri. Even if approved by the MoPSC, Ameren Missouri is not required to implement an energy efficiency plan. There is no date by which the MoPSC must act with respect to the proposed customer energy efficiency plan. Ameren Missouri cannot predict the level of investment, net shared benefits, or performance incentive that the MoPSC may approve, if any, or whether it will ultimately implement a customer energy efficiency plan for the three-year period beginning in January 2016. Noranda Contract Notification Ameren Missouri supplies electricity to Norandaās aluminum smelter 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. In order to remove Noranda from its service territory, Ameren Missouri would also be required to obtain approval from the MoPSC. Sales to Noranda represented 5% of Ameren Missouriās total electric revenue in 2014. 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 IEIMAās formula rate framework, which currently extends through 2019, Ameren Illinoisā electric delivery service rates are subject to an annual revenue requirement reconciliation to its actual 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 costs incurred. As of June 30, 2015 , Ameren Illinois had recorded regulatory assets of $24 million , $102 million , and $36 million , to reflect its expected 2015, 2014, and 2013 revenue requirement reconciliation adjustments, with interest, respectively. Ameren Illinois is collecting the 2013 revenue requirement reconciliation adjustment from customers during 2015. In April 2015, Ameren Illinois filed with the ICC its annual electric delivery service formula rate update to establish the revenue requirement used for 2016 customer rates. Pending ICC approval, and if approved as filed, Ameren Illinoisā update filing would result in a $110 million increase in Ameren Illinoisā electric delivery service revenue requirement, beginning in January 2016. This update reflects an increase to the annual formula rate based on 2014 actual costs and expected net plant additions for 2015, an increase to include the 2014 revenue requirement reconciliation adjustment, and a decrease for the conclusion of the 2013 revenue requirement reconciliation adjustment, which will be fully collected from customers in 2015. In July 2015, the ICC staff submitted its calculation of the revenue requirement included in Ameren Illinoisā update filing. The ICC staff recommended adjustments that would result in a $107 million increase in Ameren Illinoisā electric delivery service revenue requirement. An ICC decision on this April 2015 filing is expected by December 2015. 2015 Natural Gas Delivery Service Rate Case In January 2015, Ameren Illinois filed a request with the ICC seeking approval to increase its annual revenues for natural gas delivery service. In an attempt to reduce regulatory lag, Ameren Illinois used a 2016 future test year in this proceeding. Additionally, the request included a proposal to implement a volume balancing adjustment for residential and small nonresidential customers. The volume balancing adjustment would ensure that changes in natural gas sales volumes do not result in an over or under collection of natural gas revenues for these rate classes. This case includes a capital structure composed of 50% common equity and a rate base of $1.2 billion . In July 2015, Ameren Illinois, the ICC staff, and certain other intervenors filed a stipulation and agreement with the ICC that would result in rates that are based on a return on common equity of 9.6% . The agreement does not address all the positions with all of the parties in the case. Based on the terms in the agreement and the unresolved positions in the case, Ameren Illinois' request seeks an annual revenue increase of $45 million , which Ameren Illinois estimates is materially identical to the ICC staffās recommendation. The ICC staff and other intervenors did not oppose the volume balancing adjustment. A decision by the ICC in this proceeding is required by December 2015, with new rates expected to be effective in January 2016. Ameren Illinois cannot predict the level of any delivery service rate changes the ICC may approve, whether the ICC will approve the volume balancing adjustment, or if the ICC will approve the agreement between Ameren Illinois, the ICC staff, and certain other intervenors. In addition, Ameren Illinois cannot predict whether any rate changes that may eventually be approved will be sufficient to enable Ameren Illinois to recover its costs and to earn a reasonable return on investments when the rate changes go into effect. 2013 Natural Gas Delivery Service Rate Order In December 2013, the ICC issued a rate order that approved an increase in Ameren Illinoisā revenues for natural gas delivery service based on a 9.1% return on common equity. In March 2014, Ameren Illinois filed with the Appellate Court of the Fourth District of Illinois an appeal of the allowed return on common equity included in the ICC's order. Ameren Illinois sought a 10.4% return on common equity in this rate case. In June 2015, the Appellate Court of the Fourth District upheld the ICCās rate order. Ameren Illinois does not intend to pursue any further appeals. 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 In July 2015, Illinois administrative law judges issued a proposed order that recommended a certificate of public convenience and necessity and project approval for the Spoon River project. The Spoon River project is a MISO-approved 35 -mile transmission line to be constructed in northwest Illinois. A final order from the ICC is expected in 2015. A certificate of public convenience and necessity is required before ATXI can proceed with right-of-way acquisition. 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 requires Ameren Illinois to make refunds and payments of $8 million to electric transmission customers, of which $6 million was outstanding as of June 30, 2015. Ameren Illinois refunded $2 million in the second quarter of 2015 as part of a separate proceeding. The settlement agreement also requires Ameren Illinois to take other actions, such as reducing common equity for electric transmission ratemaking purposes on a prospective basis. 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 MISO transmission rate base under the MISO tariff to 9.15% . Currently, the FERC-allowed base return on common equity for MISO transmission owners is 12.38% . The FERC scheduled the case for hearing proceedings, requiring a proposed order from its administrative law judge to be issued no later than November 30, 2015, which will subsequently require FERC approval. The FERC has previously utilized a calculation to establish the allowed base return on common equity, which requires multiple inputs based on observable market data specific to the utility industry and broader macroeconomic data spanning unique time periods for each return on equity complaint case. We expect observable market data for the six months ended February 11, 2015 will be used in the November 2013 complaint case. 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 MISO transmission rate base under the MISO tariff to 8.67% . The FERC scheduled the February 2015 complaint case for hearing proceedings, requiring a proposed order from its administrative law judge to be issued no later than June 30, 2016, which will subsequently require FERC approval. We expect observable market data for the six months ended December 31, 2015 will be used in the February 2015 complaint case. A 50 basis point reduction in the FERC-allowed return on common equity would reduce Ameren's and Ameren Illinois' annual earnings by an estimated $4 million and $2 million , respectively, based on 2015 projected rate base. Ameren and Ameren Illinois recorded current liabilities on their respective balance sheets as of June 30, 2015 representing their estimate of the potential refunds from the refund effective date of November 12, 2013. Amerenās and Ameren Illinoisā recorded liabilities reflect the inputs used in the FERCās calculation to establish the allowed base return on common equity, based on observable market data for the six months ended February 11, 2015, with respect to the November 2013 complaint case refund period, and based on current market data through June 30, 2015, with respect to the February 2015 complaint case refund period. Amerenās and Ameren Illinoisā liabilities also reflect the 50 basis point adder discussed below, which became effective in early January 2015. Ameren Missouri did not record a liability as of June 30, 2015 , and 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. 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. Collection of the incentive adder is deferred until the issuance of the final order addressing the initial MISO complaint case. 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. Due primarily to recent changes in vendor support for licensing efforts at the NRC, our 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 costs of the COL. Ameren Missouri intends to withdraw its COL application filed with the NRC in August 2015. |
Short-Term Debt And Liquidity
Short-Term Debt And Liquidity | 6 Months Ended |
Jun. 30, 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. The 2012 Missouri Credit Agreement and the 2012 Illinois Credit Agreement, both of which expire on December 11, 2019, were not utilized for direct borrowings during the six months ended June 30, 2015 , but were used to support commercial paper issuances and to issue letters of credit. Based on letters of credit issued under the 2012 Credit Agreements, as well as commercial paper outstanding, the aggregate amount of credit capacity available under the 2012 Credit Agreements to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, at June 30, 2015 , was $1.2 billion . Commercial Paper The following table presents commercial paper outstanding at Ameren (parent), Ameren Missouri, and Ameren Illinois as of June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Ameren (parent) $ 836 $ 585 Ameren Missouri 38 97 Ameren Illinois 12 32 Ameren Consolidated $ 886 $ 714 The following table summarizes the borrowing activity and relevant interest rates under Amerenās (parent), Ameren Missouriās, and Ameren Illinoisā commercial paper programs for the six months ended June 30, 2015 and 2014: Ameren (parent) Ameren Missouri Ameren Illinois Ameren Consolidated 2015 Average daily commercial paper outstanding $ 754 $ 84 $ 5 $ 843 Weighted-average interest rate 0.57 % 0.50 % 0.44 % 0.56 % Peak commercial paper during period (a) $ 849 $ 294 $ 39 $ 1,108 Peak interest rate 0.70 % 0.60 % 0.60 % 0.70 % 2014 Average daily commercial paper outstanding $ 328 $ 146 $ 242 $ 607 Weighted-average interest rate 0.32 % 0.31 % 0.32 % 0.32 % Peak commercial paper during period (a) $ 503 $ 495 $ 300 $ 907 Peak interest rate 0.35 % 0.70 % 0.34 % 0.70 % (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 Companiesā compliance with financial covenants in the 2012 Credit Agreements. See Note 4 - Short-term Debt and Liquidity under Part II, Item 8, in the Form 10-K for a detailed description of these provisions. The 2012 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 2012 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 June 30, 2015 , the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the 2012 Credit Agreements, were 51% , 50% , and 46% , for Ameren, Ameren Missouri, and Ameren Illinois, respectively. In addition, under the 2012 Illinois Credit Agreement and, by virtue of the cross-default provisions of the 2012 Missouri Credit Agreement, under the 2012 Missouri Credit Agreement, Ameren is required to maintain a ratio of consolidated funds from operations plus interest expense to consolidated interest expense of at least 2.0 to 1.0. However, the interest coverage requirement only applies at such times as Ameren does not have a senior long-term unsecured credit rating of at least Baa3 from Moodyās or BBB- from S&P. As of June 30, 2015 , Ameren exceeded the rating requirements; therefore, the interest coverage requirement was not applicable. Failure of a borrower to satisfy a financial covenant constitutes an immediate default under the applicable 2012 Credit Agreement. The 2012 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 2012 Credit Agreement will also be deemed to constitute a default of Ameren under such agreement. Defaults include a cross-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 2012 Credit Agreement). However, under the default provisions of the 2012 Credit Agreements, any default of Ameren under any 2012 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 2012 Credit Agreement. Further, the 2012 Credit Agreement default provisions provide that an Ameren default under any of the 2012 Credit Agreements does not constitute a default by Ameren Missouri or Ameren Illinois. None of the Ameren Companies' credit agreements or financing arrangements contain credit rating triggers that would cause a default or acceleration of repayment of outstanding balances. The Ameren Companies were in compliance with the covenants in their credit agreements at June 30, 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 a lender. Surplus internal funds are contributed to the utility money pool from participants. The primary sources of external funds for the utility money pool are the 2012 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 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 utility 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 utility money pool for both the three and six months ended June 30, 2015 , was 0.08% ( 2014 - 0.19% and 0.29% , respectively). See Note 8 - Related Party Transactions for the amount of interest income and expense from the money pool arrangements recorded by the Ameren Companies for the three and six months ended June 30, 2015 and 2014 . |
Long-Term Debt And Equity Finan
Long-Term Debt And Equity Financings | 6 Months Ended |
Jun. 30, 2015 | |
Long-Term Debt And Equity Financings [Abstract] | |
LONG-TERM DEBT AND EQUITY FINANCINGS | LONG-TERM DEBT AND EQUITY Ameren Missouri In March 2015, Ameren Missouri received cash capital contributions of $224 million from Ameren (parent). 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. Indenture Provisions and Other Covenants Ameren Missouriās and Ameren Illinoisā 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 companiesā ability to issue bonds or preferred stock. The following table summarizes the required and actual interest coverage ratios, and dividend coverage ratios, and bonds and preferred stock issuable as of June 30, 2015 , at an assumed annual 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 ā„2.0 3.5 $ 3,305 ā„2.5 94.4 $ 2,095 Ameren Illinois ā„2.0 6.7 3,533 (d) ā„1.5 2.8 203 (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 companyās 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 2012 Illinois Credit Agreement. (e) Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinoisā articles of incorporation. Ameren Missouri and Ameren Illinois and certain other 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 āproperly included in capital account.ā 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 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 Illinoisā 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 committed to the FERC to maintain a minimum of 30% equity in its capital structure. As of June 30, 2015 , Ameren Illinois had 53% equity in its capital structure. In order for the Ameren Companies to issue securities in the future, we have to comply with all applicable requirements in effect at the time of any such issuances. Off-Balance-Sheet Arrangements At June 30, 2015 , none of the Ameren Companies had any off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business. None of the Ameren Companies expect to engage in any significant off-balance-sheet financing arrangements in the near future. See Note 12 - Divestiture Transactions and Discontinued Operations for Ameren (parent) guarantees and letters of credit issued to support New AER based on the transaction agreement with IPH. |
Other Income and Expenses
Other Income and Expenses | 6 Months Ended |
Jun. 30, 2015 | |
Other Nonoperating Income (Expense) [Abstract] | |
OTHER INCOME AND EXPENSES | OTHER INCOME AND EXPENSES The following table presents the components of āOther Income and Expensesā in the Ameren Companiesā statements of income for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Ameren: (a) Miscellaneous income: Allowance for equity funds used during construction $ 6 $ 9 $ 11 $ 16 Interest income on industrial development revenue bonds 6 7 13 14 Interest income 4 2 8 5 Other ā 3 3 4 Total miscellaneous income $ 16 $ 21 $ 35 $ 39 Miscellaneous expense: Donations $ 2 $ 1 $ 10 $ 6 Other 4 3 7 7 Total miscellaneous expense $ 6 $ 4 $ 17 $ 13 Ameren Missouri: Miscellaneous income: Allowance for equity funds used during construction $ 5 $ 8 $ 9 $ 15 Interest income on industrial development revenue bonds 6 7 13 14 Interest income 1 1 1 1 Total miscellaneous income $ 12 $ 16 $ 23 $ 30 Miscellaneous expense: Donations $ 1 $ 1 $ 3 $ 3 Other 1 1 2 3 Total miscellaneous expense $ 2 $ 2 $ 5 $ 6 Ameren Illinois: Miscellaneous income: Allowance for equity funds used during construction $ 1 $ 1 $ 2 $ 1 Interest income 3 1 7 3 Other ā 3 2 4 Total miscellaneous income $ 4 $ 5 $ 11 $ 8 Miscellaneous expense: Donations $ 1 $ ā $ 4 $ 3 Other 1 1 3 2 Total miscellaneous expense $ 2 $ 1 $ 7 $ 5 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Derivative Financial Instrument
Derivative Financial Instruments | 6 Months Ended |
Jun. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
DERIVATIVE FINANCIAL INSTRUMENTS | NOTE 6 - 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: ā¢ 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; ā¢ market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; and ā¢ 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 June 30, 2015 , and December 31, 2014 . As of June 30, 2015 , these contracts ran through October 2017, March 2021, May 2032, and December 2016 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) 39 (b) 39 50 (b) 50 Natural gas (in mmbtu) 29 127 156 28 108 136 Power (in megawatthours) 1 10 11 1 11 12 Uranium (pounds in thousands) 316 (b) 316 332 (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 7 - Fair Value Measurements for a 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 does not qualify for the NPNS exception, we review the contract to determine if 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 June 30, 2015 , and December 31, 2014 , all contracts that qualify for hedge accounting received 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 instruments, none of which were designated as hedging instruments, as of June 30, 2015 , and December 31, 2014 : Balance Sheet Location Ameren Missouri Ameren Illinois Ameren 2015 Fuel oils Other current assets $ 1 $ ā $ 1 Natural gas Other assets ā 1 1 Power Other current assets 29 ā 29 Total assets $ 30 $ 1 $ 31 Fuel oils Other current liabilities $ 14 $ ā $ 14 Other deferred credits and liabilities 5 ā 5 Natural gas MTM derivative liabilities (a) 24 (a) Other current liabilities 4 ā 28 Other deferred credits and liabilities 7 14 21 Power MTM derivative liabilities (a) 11 (a) Other current liabilities 2 ā 13 Other deferred credits and liabilities ā 154 154 Uranium Other current liabilities 2 ā 2 Total liabilities $ 34 $ 203 $ 237 2014 Fuel oils Other current assets $ 2 $ ā $ 2 Natural gas Other current assets 1 1 2 Power Other current assets 15 ā 15 Total assets $ 18 $ 1 $ 19 Fuel oils Other current liabilities $ 22 $ ā $ 22 Other deferred credits and liabilities 7 ā 7 Natural gas MTM derivative liabilities (a) 31 (a) Other current liabilities 6 ā 37 Other deferred credits and liabilities 6 13 19 Power MTM derivative liabilities (a) 11 (a) Other current liabilities 3 ā 14 Other deferred credits and liabilities ā 131 131 Uranium Other current liabilities 2 ā 2 Total liabilities $ 46 $ 186 $ 232 (a) Balance sheet line item not applicable to registrant. The following table presents the cumulative amount of pretax net gains (losses) on all derivative instruments deferred in regulatory assets or regulatory liabilities as of June 30, 2015 , and December 31, 2014 : Ameren Missouri Ameren Illinois Ameren 2015 Fuel oils derivative contracts (a) $ (19 ) $ ā $ (19 ) Natural gas derivative contracts (b) (11 ) (37 ) (48 ) Power derivative contracts (c) 27 (165 ) (138 ) Uranium derivative contracts (d) (2 ) ā (2 ) 2014 Fuel oils derivative contracts $ (29 ) $ ā $ (29 ) Natural gas derivative contracts (11 ) (43 ) (54 ) Power derivative contracts 12 (142 ) (130 ) Uranium derivative contracts (2 ) ā (2 ) (a) Represents net losses associated with fuel oils derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās rail transportation surcharges for coal through December 2017. Current gains deferred as regulatory liabilities include $1 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $14 million at Ameren and Ameren Missouri. (b) Represents net losses associated with natural gas derivative contracts. These contracts are a partial hedge of natural gas requirements through March 2021 at Ameren and Ameren Missouri and through October 2018 at Ameren Illinois. Current losses deferred as regulatory assets include $28 million , $4 million , and $24 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. (c) Represents net gains (losses) associated with power derivative contracts. These contracts are a partial hedge of power price requirements through May 2032 at Ameren and Ameren Illinois and through December 2016 at Ameren Missouri. Current gains deferred as regulatory liabilities include $29 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $13 million , $2 million , and $11 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. (d) Represents net losses on uranium derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās uranium requirements through January 2017. Current losses deferred as regulatory assets include $2 million at Ameren and Ameren Missouri. 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 June 30, 2015 , and December 31, 2014 : Gross Amounts Not Offset in the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount 2015 Assets: Ameren Missouri $ 30 $ 3 $ ā $ 27 Ameren Illinois 1 ā ā 1 Ameren $ 31 $ 3 $ ā $ 28 Liabilities: Ameren Missouri $ 34 $ 3 $ 2 $ 29 Ameren Illinois 203 ā ā 203 Ameren $ 237 $ 3 $ 2 $ 232 2014 Assets: Ameren Missouri $ 18 $ 5 $ ā $ 13 Ameren Illinois 1 ā ā 1 Ameren $ 19 $ 5 $ ā $ 14 Liabilities: Ameren Missouri $ 46 $ 5 $ 5 $ 36 Ameren Illinois 186 ā ā 186 Ameren $ 232 $ 5 $ 5 $ 222 (a) Cash collateral received reduces gross asset balances and is included in āOther current liabilitiesā and āOther deferred credits and liabilitiesā on the balance sheet. Cash collateral posted reduces gross liability balances and is included in āOther current assetsā and āOther assetsā 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. As of June 30, 2015 , if counterparty groups were to fail completely to perform on contracts, Ameren, Ameren Missouri, and Ameren Illinois' maximum exposures were $11 million , $11 million , and $- million, respectively. 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 June 30, 2015 , the potential loss after consideration of the application of master netting arrangements or similar agreements and collateral held for Ameren, Ameren Missouri, and Ameren Illinois was $11 million , $11 million , and $- million, respectively. Derivative Instruments with Credit Risk-Related Contingent Features Our commodity contracts contain collateral provisions tied to the Ameren Companiesā 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 June 30, 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 could be required to be posted with counterparties. 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 June 30, 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 $ 80 $ 3 $ 73 Ameren Illinois 77 ā 72 Ameren $ 157 $ 3 $ 145 (a) Prior to 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 | 6 Months Ended |
Jun. 30, 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 three hierarchy levels. See Note 8 - Fair Value Measurements under Part II, Item 8, of the Form 10-K for information related to hierarchy levels. 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 for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of June 30, 2015 : Fair Value Weighted Average Assets Liabilities Valuation Technique(s) Unobservable Input Range Level 3 Derivative asset and liability - commodity contracts (a) : Ameren Fuel oils $ 1 $ (2 ) Option model Volatilities(%) (b) 32 - 50 37 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.40 (d) Natural gas ā (1 ) Discounted cash flow Nodal basis($/mmbtu) (e) (0.60) - 0 (0.40) Counterparty credit risk(%) (b)(c) 0.21 - 2.01 0.83 Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Power (f) 29 (167 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (g) 26 - 45 31 Estimated auction price for FTRs($/MW) (e) (1,006) - 1,606 184 Nodal basis($/MWh) (e) (11) - (1) (3) Counterparty credit risk(%) (b)(c) 0.39 - 13.86 8.64 Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 3 - 6 4 Escalation rate(%) (e)(h) 2 (d) Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 36 - 39 37 Ameren Missouri Fuel oils $ 1 $ (2 ) Option model Volatilities(%) (b) 32 - 50 37 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.40 (d) Power (f) 29 (2 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (b) 26 - 45 34 Estimated auction price for FTRs($/MW) (e) (1,006) - 1,606 184 Nodal basis($/MWh) (b) (11) - (4) (9) Counterparty credit risk(%) (b)(c) 0.39 - 13.86 8.64 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 36 - 39 37 Ameren Illinois Natural gas $ ā $ (1 ) Discounted cash flow Nodal basis($/mmbtu) (e) (0.60) - 0 (0.40) Counterparty credit risk(%) (b)(c) 0.21 - 2.01 0.83 Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Power (f) ā (165 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (e) 27 - 37 30 Nodal basis($/MWh) (e) (6) - (1) (3) Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 3 - 6 4 Escalation rate(%) (e)(h) 2 (d) Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 (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 lower (higher) fair value measurement. (c) 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. (d) Not applicable. (e) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (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 due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. (h) Escalation rate applies to power prices 2026 and beyond. The following table describes the valuation techniques and unobservable inputs for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of December 31, 2014 : Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Level 3 Derivative asset and liability ā commodity contracts (a) : Ameren Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (b) 3 - 39 32 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Escalation rate(%) (e)(f) 5 (d) Natural Gas 1 (2 ) Option model Volatilities(%) (b) 31 - 144 63 Nodal basis($/mmbtu) (e) (0.40) - 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (e) (0.40) - 0.10 (0.20) Counterparty credit risk(%) (b)(c) 0.43 - 13 3 Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Power (g) 11 (144 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (h) 27 - 50 32 Estimated auction price for FTRs($/MW) (e) (1,833) - 2,743 171 Nodal basis($/MWh) (e) (6) - 0 (2) Counterparty credit risk(%) (b)(c) 0.26 (d) Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 4 - 5 4 Escalation rate(%) (e)(i) 0 - 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 35 - 40 36 Ameren Missouri Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (b) 3 - 39 32 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Escalation rate(%) (e)(f) 5 (d) Natural Gas ā (1 ) Option model Volatilities(%) (b) 31 - 144 53 Nodal basis($/mmbtu) (e) (0.40) - 0 (0.30) Discounted cash flow Nodal basis($/mmbtu) (e) (0.10) (d) Counterparty credit risk(%) (b)(c) 0.57 - 13 5 Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Power (g) 11 (2 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (b) 27 - 50 32 Estimated auction price for FTRs($/MW) (e) (1,833) - 2,743 171 Counterparty credit risk(%) (b)(c) 0.26 (d) Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 35 - 40 36 Ameren Illinois Natural Gas $ 1 $ (1 ) Option model Volatilities(%) (b) 50 - 144 94 Nodal basis($/mmbtu) (e) (0.10) - 0 (0.10) Discounted cash flow Nodal basis($/mmbtu) (e) (0.40) - 0.10 (0.20) Counterparty credit risk(%) (b)(c) 0.43 - 2 0.83 Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Power (g) ā (142 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (e) 27 - 38 32 Nodal basis($/MWh) (e) (6) - 0 (2) Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 4 - 5 4 Escalation rate(%) (e)(i) 0 - 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 (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 lower (higher) fair value measurement. (c) 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. (d) Not applicable. (e) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (f) Escalation rate applies to fuel oil prices 2017 and beyond. (g) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2018. Valuations beyond 2018 use fundamentally modeled pricing by month for peak and off-peak demand. (h) The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. (i) Escalation rate applies to power prices 2026 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 the first six months of 2015 or 2014 . At June 30, 2015 , the counterparty default risk liability valuation adjustment related to derivative contracts totaled $1 million , less than $1 million , and $1 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively. At December 31, 2014 , the counterparty default risk liability valuation adjustment related to derivative contracts totaled $1 million , less than $1 million , and $1 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively. 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 June 30, 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) : Fuel oils $ ā $ ā $ 1 $ 1 Natural gas ā 1 ā 1 Power ā ā 29 29 Total derivative assets - commodity contracts $ ā $ 1 $ 30 $ 31 Nuclear decommissioning trust fund: Cash and cash equivalents $ 6 $ ā $ ā $ 6 Equity securities: U.S. large capitalization 370 ā ā 370 Debt securities: Corporate bonds ā 59 ā 59 U.S. treasury and agency securities ā 100 ā 100 Other ā 22 ā 22 Total nuclear decommissioning trust fund $ 376 $ 181 $ ā $ 557 (b) Total Ameren $ 376 $ 182 $ 30 $ 588 Ameren Derivative assets - commodity contracts (a) : Missouri Fuel oils $ ā $ ā $ 1 $ 1 Power ā ā 29 29 Total derivative assets - commodity contracts $ ā $ ā $ 30 $ 30 Nuclear decommissioning trust fund: Cash and cash equivalents $ 6 $ ā $ ā $ 6 Equity securities: U.S. large capitalization 370 ā ā 370 Debt securities: Corporate bonds ā 59 ā 59 U.S. treasury and agency securities ā 100 ā 100 Other ā 22 ā 22 Total nuclear decommissioning trust fund $ 376 $ 181 $ ā $ 557 (b) Total Ameren Missouri $ 376 $ 181 $ 30 $ 587 Ameren Derivative assets - commodity contracts (a) : Illinois Natural gas $ ā $ 1 $ ā $ 1 Liabilities: Ameren Derivative liabilities - commodity contracts (a) : Fuel oils $ 17 $ ā $ 2 $ 19 Natural gas ā 48 1 49 Power ā ā 167 167 Uranium ā ā 2 2 Total Ameren $ 17 $ 48 $ 172 $ 237 Ameren Derivative liabilities - commodity contracts (a) : Missouri Fuel oils $ 17 $ ā $ 2 $ 19 Natural gas ā 11 ā 11 Power ā ā 2 2 Uranium ā ā 2 2 Total Ameren Missouri $ 17 $ 11 $ 6 $ 34 Ameren Derivative liabilities - commodity contracts (a) : Illinois Natural gas $ ā $ 37 $ 1 $ 38 Power ā ā 165 165 Total Ameren Illinois $ ā $ 37 $ 166 $ 203 (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 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 $ ā $ ā $ 2 $ 2 Natural gas ā 1 1 2 Power ā 4 11 15 Total derivative assets - commodity contracts $ ā $ 5 $ 14 $ 19 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ ā $ ā $ 1 Equity securities: U.S. large capitalization 364 ā ā 364 Debt securities: Corporate bonds ā 63 ā 63 U.S. treasury and agency securities ā 102 ā 102 Other ā 17 ā 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ ā $ 547 (b) Total Ameren $ 365 $ 187 $ 14 $ 566 Ameren Derivative assets - commodity contracts (a) : Missouri Fuel oils $ ā $ ā $ 2 $ 2 Natural gas ā 1 ā 1 Power ā 4 11 15 Total derivative assets - commodity contracts $ ā $ 5 $ 13 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ ā $ ā $ 1 Equity securities: U.S. large capitalization 364 ā ā 364 Debt securities: Corporate bonds ā 63 ā 63 U.S. treasury and agency securities ā 102 ā 102 Other ā 17 ā 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ ā $ 547 (b) Total Ameren Missouri $ 365 $ 187 $ 13 $ 565 Ameren Derivative assets - commodity contracts (a) : Illinois Natural gas $ ā $ ā $ 1 $ 1 Liabilities: Ameren Derivative liabilities - commodity contracts (a) : Fuel oils $ 21 $ ā $ 8 $ 29 Natural gas 1 53 2 56 Power ā 1 144 145 Uranium ā ā 2 2 Total Ameren $ 22 $ 54 $ 156 $ 232 Ameren Derivative liabilities - commodity contracts (a) : Missouri Fuel oils $ 21 $ ā $ 8 $ 29 Natural gas 1 10 1 12 Power ā 1 2 3 Uranium ā ā 2 2 Total Ameren Missouri $ 22 $ 11 $ 13 $ 46 Ameren Derivative liabilities - commodity contracts (a) : Illinois Natural gas $ ā $ 43 $ 1 $ 44 Power ā ā 142 142 Total Ameren Illinois $ ā $ 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 three months ended June 30, 2015 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at April 1, 2015 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities 1 (a) 1 Settlements 2 (a) 2 Transfers out of Level 3 2 (a) 2 Ending balance at June 30, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ 3 $ (a) $ 3 Natural gas: Beginning balance at April 1, 2015 $ (1 ) $ 1 $ ā Purchases ā (1 ) (1 ) Settlements 1 (1 ) ā Ending balance at June 30, 2015 $ ā $ (1 ) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ ā $ ā Power: Beginning balance at April 1, 2015 $ 4 $ (164 ) $ (160 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities ā (4 ) (4 ) Purchases 29 ā 29 Settlements (6 ) 3 (3 ) Ending balance at June 30, 2015 $ 27 $ (165 ) $ (138 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ 1 $ (5 ) $ (4 ) Uranium: Beginning balance at April 1, 2015 $ (1 ) $ (a) $ (1 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (1 ) (a) (1 ) Ending balance at June 30, 2015 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ (1 ) $ (a) $ (1 ) (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 three months ended June 30, 2014 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at April 1, 2014 $ 1 $ (a) $ 1 Realized and unrealized gains (losses) included in regulatory assets/liabilities 1 (a) 1 Ending balance at June 30, 2014 $ 2 $ (a) $ 2 Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ 1 $ (a) $ 1 Natural gas: Beginning balance at April 1, 2014 $ ā $ ā $ ā Purchases ā 1 1 Settlements ā (1 ) (1 ) Ending balance at June 30, 2014 $ ā $ ā $ ā Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ ā $ ā Power: Beginning balance at April 1, 2014 $ 10 $ (120 ) $ (110 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (13 ) 16 3 Purchases 34 ā 34 Settlements (15 ) 1 (14 ) Transfers out of Level 3 (1 ) ā (1 ) Ending balance at June 30, 2014 $ 15 $ (103 ) $ (88 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (1 ) $ 15 $ 14 Uranium: Beginning balance at April 1, 2014 $ (5 ) $ (a) $ (5 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (4 ) (a) (4 ) Settlements 2 (a) 2 Ending balance at June 30, 2014 $ (7 ) $ (a) $ (7 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (4 ) $ (a) $ (4 ) (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 six months ended June 30, 2015 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2015 $ (6 ) $ (a) $ (6 ) Settlements 3 (a) 3 Transfers out of Level 3 2 (a) 2 Ending balance at June 30, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (a) $ ā Natural gas: Beginning balance at January 1, 2015 $ (1 ) $ ā $ (1 ) Settlements 1 (1 ) ā Ending balance at June 30, 2015 $ ā $ (1 ) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ ā $ ā Power: Beginning balance at January 1, 2015 $ 9 $ (142 ) $ (133 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (2 ) (29 ) (31 ) Purchases 29 ā 29 Settlements (9 ) 6 (3 ) Ending balance at June 30, 2015 $ 27 $ (165 ) $ (138 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (29 ) $ (29 ) Uranium: Beginning balance at January 1, 2015 $ (2 ) $ (a) $ (2 ) Ending balance at June 30, 2015 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (a) $ ā (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 six months ended June 30, 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 (1 ) (a) (1 ) Settlements (2 ) (a) (2 ) Ending balance at June 30, 2014 $ 2 $ (a) $ 2 Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ (a) $ ā Natural gas: Beginning balance at January 1, 2014 $ ā $ ā $ ā Purchases ā (1 ) (1 ) Settlements ā 1 1 Ending balance at June 30, 2014 $ ā $ ā $ ā Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ ā $ ā Power: Beginning balance at January 1, 2014 $ 19 $ (108 ) $ (89 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (18 ) 4 (14 ) Purchases 34 ā 34 Settlements (20 ) 1 (19 ) Ending balance at June 30, 2014 $ 15 $ (103 ) $ (88 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (3 ) $ 1 $ (2 ) Uranium: Beginning balance at January 1, 2014 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (4 ) (a) (4 ) Settlements 3 (a) 3 Ending balance at June 30, 2014 $ (7 ) $ (a) $ (7 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (4 ) $ (a) $ (4 ) (a) Not applicable. Transfers in 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 2 and Level 3 for power derivatives and between Level 1 and Level 3 for fuel oils 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. For the three and six months ended June 30, 2015 and 2014 , there were no transfers between Level 1 and Level 2 related to derivative commodity contracts. The following table summarizes all transfers between fair value hierarchy levels related to derivative commodity contracts for the three and six months ended June 30, 2015 , and 2014 : 2015 2014 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Three Months Transfers out of Level 3 / Transfers into Level 1 - Fuel oils $ 2 $ ā $ 2 $ ā $ ā $ ā Transfers out of Level 3 / Transfers into Level 2 - Power ā ā ā (1 ) ā (1 ) Six Months Transfers out of Level 3 / Transfers into Level 1 - Fuel oils $ 2 $ ā $ 2 $ ā $ ā $ ā The Ameren Companiesā 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 to be 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 June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Ameren: (a) Long-term debt and capital lease obligations (including current portion) $ 6,376 $ 6,919 $ 6,240 $ 7,135 Preferred stock 142 122 142 122 Ameren Missouri: Long-term debt and capital lease obligations (including current portion) $ 4,135 $ 4,492 $ 3,999 $ 4,518 Preferred stock 80 73 80 73 Ameren Illinois: Long-term debt $ 2,241 $ 2,427 $ 2,241 $ 2,517 Preferred stock 62 49 62 49 (a) Preferred stock is recorded in āNoncontrolling Interestsā on the consolidated balance sheet. |
Related Party Transactions
Related Party Transactions | 6 Months Ended |
Jun. 30, 2015 | |
Related Party Transactions [Abstract] | |
RELATED PARTY TRANSACTIONS | RELATED PARTY TRANSACTIONS Ameren (parent) and its subsidiaries have engaged in, and may in the future engage in, affiliate transactions in the normal course of business. These transactions primarily consist of power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between affiliates are reported as intercompany transactions on their respective financial statements but are eliminated in consolidation for Amerenās financial statements. For a discussion of our material related party agreements, see Note 14 - Related Party Transactions under Part II, Item 8, of the Form 10-K and the money pool arrangements discussed in Note 3 - Short-term Debt and Liquidity of this report. Electric Power Supply Agreements In April 2015, Ameren Illinois used an RFP process, administered by the IPA, to procure energy products from June 1, 2015, through May 31, 2018. Ameren Missouri was among the winning suppliers in the energy product RFP process. As a result, in 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. The following table presents the impact on Ameren Missouri and Ameren Illinois of related party transactions for the three and six months ended June 30, 2015 and 2014 . Three Months Six Months Agreement Income Statement Line Item Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Ameren Missouri power supply Operating Revenues 2015 $ 4 $ (a) $ 5 $ (a) agreements with Ameren Illinois 2014 3 (a) 3 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2015 7 1 13 2 rent and facility services 2014 4 1 9 1 Ameren Missouri and Ameren Illinois Operating Revenues 2015 1 (b) 1 (b) miscellaneous support services 2014 1 (b) 1 (b) Total Operating Revenues 2015 $ 12 $ 1 $ 19 $ 2 2014 8 1 13 1 Ameren Illinois power supply Purchased Power 2015 $ (a) $ 4 $ (a) $ 5 agreements with Ameren Missouri 2014 (a) 3 (a) 3 Ameren Illinois transmission Purchased Power 2015 (a) (b) (a) 1 services with ATXI 2014 (a) (b) (a) 1 Total Purchased Power 2015 $ (a) $ 4 $ (a) $ 6 2014 (a) 3 (a) 4 Ameren Services support services Other Operations and Maintenance 2015 $ 32 $ 30 $ 66 $ 59 agreement 2014 32 27 65 54 Money pool borrowings (advances) Interest Charges/ Miscellaneous Income 2015 $ (b) $ (b) $ (b) $ (b) 2014 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies
Commitments And Contingencies | 6 Months Ended |
Jun. 30, 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 the notes to our financial statements in this report and in our Form 10-K, will not have a material adverse effect on our results of operations, financial position, or liquidity. Reference is made to Note 1 - Summary of Significant Accounting Policies, Note 2 - Rate and Regulatory Matters, Note 14 - Related Party Transactions, Note 15 - Commitments and Contingencies, and Note 16 - Divestiture Transactions and Discontinued Operations under Part II, Item 8, of the Form 10-K. See also Note 1 - Summary of Significant Accounting Policies, Note 2 - Rate and Regulatory Matters, Note 8 - Related Party Transactions, Note 10 - Callaway Energy Center, and Note 12 - Divestiture Transactions and Discontinued Operations in this report. Callaway Energy Center The following table presents insurance coverage at Ameren Missouriās Callaway energy center at June 30, 2015 . The property coverage and the nuclear liability coverage must be renewed on April 1 and January 1, respectively, of each year. Both coverages were renewed in 2015. Type and Source of Coverage Maximum Coverages Maximum Assessments for Single Incidents Public liability and nuclear worker liability: American Nuclear Insurers $ 375 $ ā Pool participation 12,986 (a) 128 (b) $ 13,361 (c) $ 128 Property damage: NEIL $ 2,750 (d) $ 27 (e) European Mutual Association for Nuclear Insurance 500 (f) ā $ 3,250 $ 27 Replacement power: NEIL $ 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 $128 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 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 NEILās policies, subject to an industrywide aggregate policy 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 Amerenās and Ameren Missouriās results of operations, financial position, or liquidity. Other Obligations To supply a portion of the fuel requirements of Ameren Missouriās energy centers, Ameren Missouri has entered into various long-term commitments for the procurement of coal, natural gas, nuclear fuel, and methane gas. Additionally, Ameren Missouri and Ameren Illinois also have entered into various long-term commitments for purchased power and natural gas for distribution. For a complete listing of our obligations and commitments, see Note 15 - Commitments and Contingencies under Part II, Item 8 of the Form 10-K. At June 30, 2015 , total other obligations related to commitments for coal, natural gas, nuclear fuel, purchased power, methane gas, equipment, customer energy efficiency program expenditures and meter reading services, among other agreements, at Ameren, Ameren Missouri, and Ameren Illinois were $5,110 million , $3,247 million , and $1,822 million , respectively. In April 2015, Ameren Illinois used an RFP process, administered by the IPA, to procure energy products from June 1, 2015, through May 31, 2018. Ameren Illinois contracted to purchase approximately 5,526,000 megawatthours of energy products for $185 million during this period. The procured energy products are included in Amerenās and Ameren Illinoisā obligations discussed above. See Note 8 - Related Party Transactions in this report for additional information regarding energy product agreements between Ameren Missouri and Ameren Illinois as a result of this RFP process. 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 existing or new 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, or 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 is developing and implementing 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 proposed or promulgated 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 of CCR and CCR landfills and impoundments; 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 waste water 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 Missouriās energy centers. Certain of these new and proposed regulations, if adopted, 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 the future regulations are unknown, the combined effects of the new and proposed environmental regulations could result in significant capital expenditures and increased operating costs for Ameren and Ameren Missouri. 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 . 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 Missouriās energy centers, or require capital investment. Ameren and Ameren Missouri expect these costs would be recoverable through rates, subject to MoPSC prudence review, but the nature and timing of costs, as well as the applicable regulatory framework, could result in regulatory lag. As of June 30, 2015 , Ameren and Ameren Missouri estimate capital expenditures of $350 million to $400 million through 2019 to comply with existing environmental regulations. Considerable uncertainty remains in this estimate. 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. This estimate does not include the impacts of the Clean Power Planās reduction in emissions of CO 2 , but does include our preliminary estimate of the capital expenditures required for the CCR regulations that were published in April 2015, both of which are discussed below. The estimate also includes capital expenditures associated with MATS compliance discussed below. 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 Missouri has two scrubbers at its Sioux energy center, which are used to reduce SO 2 emissions and other pollutants. Ameren Missouri's compliance plan assumes the installation of additional controls, including mercury control technology at multiple energy centers within its coal-fired fleet through 2019. However, Ameren Missouri continues to evaluate its operations and options to determine how to comply with the CSAPR, the MATS, and other recently finalized or proposed EPA regulations. Ameren Missouri may be required to install additional pollution controls within the next six to 10 years. In addition, Ameren Missouri is currently evaluating the recently finalized Clean Power Plan and potential compliance plans for the rule. The following sections describe the more significant new or proposed environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. Clean Air Act Both 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 on January 1, 2015, for SO 2 and annual NO x reductions, and on May 1, 2015, for ozone season NO x reductions. There will be further emission reduction requirements in 2017 and potentially more in subsequent years. Ameren Missouri expects to have sufficiently reduced emissions and have sufficient allowances to avoid purchasing allowances to comply with CSAPR for 2015. To achieve compliance with CSAPR, Ameren Missouri operates two scrubbers at its Sioux energy center and burns ultra-low sulfur coal. Ameren Missouri does not expect to make additional capital investments to comply with the current CSAPR requirements. However, Ameren Missouri expects to incur additional operations and maintenance costs to lower its emissions at one or more of its energy centers for compliance with the CSAPR in future years. These higher operations and maintenance 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. Ameren Missouri's Labadie and Meramec energy centers were granted extensions. In June 2015, the United States Supreme Court remanded a case challenging the MATS back to the United States Court of Appeals for the District of Columbia Circuit and ruled that the EPA must consider costs before deciding whether regulation of emissions of mercury and other hazardous air pollutants from power plants is appropriate and necessary. Unless the United States Court of Appeals for the District of Columbia Circuit acts to stay implementation of the MATS, Ameren Missouri expects to make additional capital investments at its Labadie and Meramec energy centers to comply with the MATS by April 2016. These capital expenditure investments are included in Ameren's and Ameren Missouri's estimate of capital expenditures to comply with existing environmental regulations above. In addition, Ameren Missouri is incurring additional operations and maintenance costs to lower its emissions at its energy centers in compliance with the MATS. These higher operations and maintenance costs are expected to be collected from customers through the FAC or higher base rates. In December 2014, the EPA published its proposal to strengthen the 2008 national ambient air quality standard for ozone. A final standard is expected in October 2015, after which states that do not meet the standard must develop and implement plans to achieve compliance. Ameren Missouri is currently evaluating the proposed standard and the possible effects on its operations. Greenhouse Gas Regulation In August 2015, the EPA issued the finalized version of the Clean Power Plan, which sets forth CO 2 emissions standards that will be applicable to existing power plants. The finalized regulations will become effective 60 days after publication in the Federal Register and differ significantly from the EPAās originally proposed June 2014 rule. Under the Clean Power Plan, Ameren Missouri expects to incur increased net fuel and operating costs, and new or accelerated capital expenditures, in addition to making modifications to existing operations in order to achieve compliance. The states of Missouri and Illinois are required to each significantly reduce their greenhouse gas emissions below 2005 levels by 2030. States are required to submit preliminary compliance plans to the EPA as early as 2016, although extensions until 2018 are available. The rule contains interim compliance periods which commence in 2022. Ameren Missouri is in the preliminary stage of evaluating the Clean Power Plan and the potential impacts to its operations, including those related to electric system reliability and its level of investment in customer energy efficiency programs. Significant uncertainty exists regarding the impact of the Clean Power Plan, as the finalized rule is different from the originally proposed rule and will be subject to legal challenges, which could result in the amount and timing of CO 2 emissions standards being revised. Compliance measures could result in the closure or alteration of the operation of some of Ameren Missouriās 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 and modified power plants. These new standards establish separate emissions limits for new natural-gas fired plants and new coal-fired plants. Federal and state legislation or regulations that mandate limits on the emission of greenhouse gases may result in significant increases in capital expenditures and operating costs, which could lead to increased liquidity needs and higher financing costs. These compliance costs could be prohibitive at some of Ameren Missouriās energy centers. Mandatory limits on the emission of greenhouse gases could increase costs for Ameren Missouriās 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 Illinoisā 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 greenhouse gas limitations to the extent that the investments are reflected and recovered timely 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. In January 2012, the district court granted, in part, Ameren Missouri's motion to dismiss various aspects of the EPA's penalty claims. The EPA's claims for unspecified injunctive relief remain. Ameren Missouri anticipates a trial of this case will occur in 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 future results of operations, financial position, and liquidity of Ameren and Ameren Missouri. A resolution could result in increased capital expenditures for the installation of pollution control equipment, increased operations and maintenance expenses, and penalties. 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 published the final rule applicable to cooling water intake structures at existing power plants. The rule requires a case-by-case evaluation and plan for reducing the mortality of aquatic organisms impinged on the facilityās intake screens or entrained through the plant's cooling water system. Implementation of this rule will be administered through each power plantās water discharge permitting process. All of Ameren Missouriās coal-fired and nuclear energy centers are subject to this rule. The rule could have an adverse effect on Amerenās and Ameren Missouriās 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 timely in electric rates charged to its customers. In April 2013, the EPA announced its proposal to revise the effluent limitation guidelines applicable to steam electric generating units under the Clean Water Act. Effluent limitation guidelines are national standards for wastewater discharges to surface water that are based on the effectiveness of available control technology. The EPA's proposed rule raised several compliance options that would prohibit effluent discharges of certain, but not all, waste streams and impose more stringent limitations on certain components in wastewater discharges from power plants. If the rule is enacted as proposed, Ameren Missouri would be subject to the revised limitations beginning as early as July 1, 2017, but no later than July 1, 2022. The EPA is expected to issue final guidelines in September 2015. Ash Management In December 2014, the EPA issued regulations regarding the management and disposal of CCR, which will affect future CCR disposal and handling costs at Ameren Missouri's energy centers. The final CCR regulations were published in April 2015. 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 the second quarter of 2015, Ameren and Ameren Missouri recorded an increase to their AROs associated with CCR storage facilities as a result of the new regulations. 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. Ameren Missouri expects certain of its ash ponds could be closed within the next five years. The new regulations do not apply to inactive ash ponds at plants no longer in operation, such as Amerenās 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 June 30, 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 at these sites by 2018. 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. To be recoverable, such costs must be prudently incurred. Costs are subject to annual review by the ICC. As of June 30, 2015 , Ameren Illinois estimated the obligation related to these former MGP sites at $240 million to $309 million . Ameren and Ameren Illinois recorded a liability of $240 million to represent the 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 June 30, 2015 , Ameren Illinois estimated the obligation related to the landfill 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 June 30, 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 June 30, 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 various 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 June 30, 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 for this site, 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 June 30, 2015 , Ameren Missouri estimated and recorded a $1 million liability related to the remaining cleanup of the site. 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. In 2010, Ameren Missouri sued an insurance company that was providing Ameren Missouri with liability coverage on the date of the Taum Sauk incident. In the litigation, Ameren Missouri claims that the insurance company breached its duty to indemnify Ameren Missouri for losses resulting from the incident. In September 2014, the United States District Court for the Eastern District of Missouri ordered the case to be transferred to the United States District Court for the Southern District of New York. The transfer order was stayed pending Ameren Missouriās October 2014 appeal of the order to the United States Court of Appeals for the Eight Circuit. In July 2015, the court of appeals upheld the order transferring the case to the United States District Court for the Southern District of New York, and the case was subsequently transferred. As of June 30, 2015 , Ameren Missouri had a net insurance receivable balance of $41 million . The insurance claim was $53 million as of June 30, 2015. Ameren Missouri expects to collect this receivable from the insurance company in the pending litigation described above. This receivable is included in āOther assetsā on Amerenās and Ameren Missouriās balance sheets as of June 30, 2015 . Ameren's and Ameren Missouri's results of operations, financial position, and liquidity could be adversely affected if Ameren Missouri's insurance receivable balance is not collected. 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 current 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 73 as the average number of parties as of June 30, 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 the Ameren Companies as of June 30, 2015 : Ameren Ameren Missouri Ameren Illinois Total (a) 1 28 36 49 (a) Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. As of June 30, 2015 , Ameren, Ameren Missouri, and Ameren Illinois had liabilities of $8 million , $3 million , and $5 million , respectively, recorded to represent their best estimate 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 cash expenditures in excess of the amount included in base electric rates are to be recovered from a trust fund that was established when Ameren acquired IP. At June 30, 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 customers within IPās historical service territory. |
Callaway Energy Center
Callaway Energy Center | 6 Months Ended |
Jun. 30, 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 and other utilities that own and operate those 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 annually to review the nuclear waste fee 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. Ameren Missouri has sufficient installed capacity at the Callaway energy center to store its spent nuclear fuel generated through 2020, and is constructing additional dry spent fuel storage capacity. 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. 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 a dry spent fuel storage facility that Ameren Missouri is constructing at its Callaway energy center. Ameren Missouri intends to begin transferring spent fuel assemblies to this facility in 2015. Ameren Missouri will continue to apply for reimbursement from the DOE for the cost to construct, operate, and decommission the dry spent fuel storage facility along with related allowable costs. In March 2015, the NRC approved Ameren Missouriās application to extend its Callaway energy center's operating license from 2024 to 2044. 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 centerās 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 NRCās decision to approve Ameren Missouriās operating license extension application, an updated cost study and a revised funding analysis were filed with the MoPSC in April 2015. Ameren Missouriās April 2015 filing supported no change in electric service rates. There is no time requirement by which the MoPSC must issue an order regarding the decommissioning cost included in Ameren Missouriās 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. |
Retirement Benefits
Retirement Benefits | 6 Months Ended |
Jun. 30, 2015 | |
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract] | |
RETIREMENT BENEFITS | RETIREMENT BENEFITS Amerenās pension plans are funded in compliance with income tax regulations and to meet federal funding or regulatory requirements. As a result, Ameren expects to fund its pension plans at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering Amerenās assumptions at June 30, 2015 , the planās estimated investment performance through June 30, 2015 , and Amerenās pension funding policy, Ameren expects to make annual contributions of $25 million to $115 million through 2019, with aggregate estimated contributions of $290 million . These amounts are estimates which may change with actual investment performance, changes in interest rates, any pertinent changes in government regulations, and any voluntary contributions. Separately, our policy for postretirement benefits is primarily to fund the voluntary employeesā beneficiary association trusts to match the annual postretirement expense. The following table presents the components of the net periodic benefit cost (benefit) incurred for Amerenās pension and postretirement benefit plans for the three and six months ended June 30, 2015 and 2014 : Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $ 22 $ 19 $ 46 $ 40 $ 6 $ 4 $ 11 $ 9 Interest cost 43 42 87 91 12 12 24 25 Expected return on plan assets (62 ) (57 ) (124 ) (114 ) (17 ) (16 ) (34 ) (32 ) Amortization of: Prior service benefit ā ā ā ā (1 ) (1 ) (2 ) (2 ) Actuarial loss (gain) 19 12 37 24 2 (2 ) 3 (3 ) Settlement loss 1 ā 1 ā ā ā ā ā Net periodic benefit cost (benefit) $ 23 $ 16 $ 47 $ 41 $ 2 $ (3 ) $ 2 $ (3 ) Ameren Missouri and Ameren Illinois are responsible for their respective shares of Amerenās pension and postretirement costs. The following table presents the pension costs and the postretirement benefit costs (benefit) incurred for the three and six months ended June 30, 2015 and 2014 : Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Ameren Missouri $ 13 $ 8 $ 28 $ 25 $ 3 $ 1 $ 4 $ 2 Ameren Illinois 10 7 19 15 (1 ) (3 ) (2 ) (4 ) Other ā 1 ā 1 ā (1 ) ā (1 ) Ameren (a) $ 23 $ 16 $ 47 $ 41 $ 2 $ (3 ) $ 2 $ (3 ) (a) Includes amounts for Ameren registrants and nonregistrant subsidiaries. |
Divestiture Transactions and Di
Divestiture Transactions and Discontinued Operations | 6 Months Ended |
Jun. 30, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | |
DIVESTITURE TRANSACTIONS AND DISCONTINUED OPERATIONS | 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. The transaction agreement with IPH, as amended, provided that if the Elgin, Gibson City, and Grand Tower gas-fired energy centers were subsequently sold by Medina Valley and if Medina Valley received additional proceeds from such sale, Medina Valley would 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 $17 million of the purchase price to be held in escrow until January 31, 2016, to fund certain indemnity obligations, if any, of Medina Valley. The Rockland Capital escrow receivable balance and the corresponding payable due to Genco is reflected on Ameren's June 30, 2015 consolidated balance sheet in "Other current assets" and in "Other current liabilities," respectively. Medina Valley expects to pay Genco any remaining portion of the escrow balance on January 31, 2016. Ameren did not record a gain from its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers. Discontinued Operations Presentation See Note 16 - Divestiture Transactions and Discontinued Operations under Part II, Item 8, of the Form 10-K for additional information related to disposal groups. 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 IRSā audit for 2013. During the second quarter of 2015, based on the completion of the IRS audit, Ameren removed the reserve for unrecognized tax benefits recorded in 2013 and recognized a tax benefit from discontinued operations. See Note 1 - Summary of Significant Accounting Policies for additional information regarding the Ameren Companiesā uncertain tax positions. The following table presents the components of discontinued operations in Ameren's consolidated statement of income for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Operating revenues $ ā $ ā $ ā $ 1 Operating benefits (expenses) ā (1 ) 3 (3 ) Operating income (loss) before income tax ā (1 ) 3 (2 ) Income tax benefit 52 ā 49 ā Income (loss) from discontinued operations, net of taxes $ 52 $ (1 ) $ 52 $ (2 ) The following table presents the carrying amounts of the components of assets and liabilities of Amerenās discontinued operations, which consist primarily of AROs and related deferred income tax assets associated with the abandoned Meredosia and Hutsonville energy centers, at June 30, 2015 , and December 31, 2014: June 30, 2015 December 31, 2014 Assets of discontinued operations Accumulated deferred income taxes, net $ 15 $ 15 Total assets of discontinued operations $ 15 $ 15 Liabilities of discontinued operations Accounts payable and other current obligations $ 2 $ 1 Asset retirement obligations 30 32 Total liabilities of discontinued operations $ 32 $ 33 Pursuant to the IPH transaction agreement, as amended, Ameren is obligated to pay up to $25 million for certain liabilities as of June 30, 2015 , which were included in "Other current liabilities" on Ameren's June 30, 2015 consolidated balance sheet. The note receivable from Marketing Company related to the cash collateral support provided to New AER was $9 million and $12 million at June 30, 2015, and December 31, 2014, respectively, and was reflected on Ameren's consolidated balance sheet in "Miscellaneous accounts and notes receivable.ā This receivable is due to Ameren, with interest, on December 2, 2015, or sooner as cash collateral requirements are reduced. In addition, as of June 30, 2015, if Amerenās credit ratings had been below investment grade, Ameren could have been required to post additional cash collateral in support of New AER in the amount of $19 million , which includes $6 million currently covered by Ameren guarantees discussed below. This cash collateral support is part of Amerenās obligation to provide certain limited credit support to New AER until December 2, 2015, as discussed below. Ameren Guarantees and Letters of Credit The IPH transaction agreement, as amended, requires Ameren to maintain its financial obligations with respect to all credit support provided to New AER as of the December 2, 2013 closing date of the divestiture. Ameren must also provide such additional credit support as required by contracts entered into prior to the closing date, in each case until December 2, 2015. IPH shall indemnify Ameren for any payments Ameren makes pursuant to these credit support obligations if the counterparty does not return the posted collateral to Ameren. IPH's indemnification obligation is secured by certain AERG and Genco assets. In addition, Dynegy has provided a limited guarantee of $25 million to Ameren pursuant to which Dynegy will, among other things, guarantee IPH's indemnification obligations until December 2, 2015. In addition to the $25 million of liabilities recorded on Amerenās June 30, 2015 consolidated balance sheet, Ameren had a total of $79 million in guarantees outstanding for New AER that were not recorded on Amerenās June 30, 2015 consolidated balance sheet. Almost all of these guarantees support Marketing Company for physically and financially settled power transactions with its counterparties that were in place at the December 2, 2013 closing of the divestiture, as well as for Marketing Company's clearing broker and other service agreements. If Marketing Company did not fulfill its obligations to these counterparties who had active open positions as of June 30, 2015 , Ameren would have been required under its guarantees to provide $ 6 million to the counterparties. Also, at June 30, 2015 , Ameren had issued letters of credit totaling $9 million as credit support on behalf of New AER. Ameren has not recorded a liability for these contingent obligations because it does not believe a payment with respect to any of these guarantees or letters of credit was probable as of June 30, 2015 . |
Segment Information
Segment Information | 6 Months Ended |
Jun. 30, 2015 | |
Segment Reporting [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 of the operations of Ameren Missouriās business as described in Note 1 - Summary of Significant Accounting Policies. The Ameren Illinois segment for both Ameren and Ameren Illinois includes all of the operations of Ameren Illinoisā business 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 following table presents information about the reported revenues and net income attributable to Ameren Corporation from continuing operations for the three and six months ended June 30, 2015 and 2014 , and total assets of continuing operations as of June 30, 2015 , and December 31, 2014 : Three Months Ameren Missouri Ameren Illinois Other Intersegment Eliminations Ameren 2015 External revenues $ 872 $ 512 $ 17 $ ā $ 1,401 Intersegment revenues 12 1 ā (13 ) ā Net income attributable to Ameren Corporation from continuing operations 61 31 6 ā 98 2014 External revenues $ 893 $ 518 $ 8 $ ā $ 1,419 Intersegment revenues 7 1 ā (8 ) ā Net income (loss) attributable to Ameren Corporation from continuing operations 126 28 (4 ) ā 150 Six Months 2015 External revenues $ 1,665 $ 1,256 $ 36 $ ā $ 2,957 Intersegment revenues 19 2 1 (22 ) ā Net income attributable to Ameren Corporation from continuing operations 102 84 20 ā 206 2014 External revenues $ 1,704 $ 1,292 $ 17 $ ā $ 3,013 Intersegment revenues 13 1 1 (15 ) ā Net income (loss) attributable to Ameren Corporation from continuing operations 173 81 (7 ) ā 247 As of June 30, 2015: Total assets $ 13,721 $ 8,500 $ 1,036 $ (120 ) $ 23,137 (a) As of December 31, 2014: Total assets $ 13,541 $ 8,381 $ 942 $ (203 ) $ 22,661 (a) (a) Excludes total assets from discontinued operations of $15 million as of June 30, 2015 , and December 31, 2014. |
Summary Of Significant Accoun22
Summary Of Significant Accounting Policies (Policies) | 6 Months Ended |
Jun. 30, 2015 | |
Accounting Policies [Abstract] | |
Consolidation | financial statements are prepared on a consolidated basis, and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Missouri and Ameren Illinois have no subsidiaries, and therefore their financial statements are not prepared on a consolidated basis. 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. The results of operations of an interim period may not give a true indication of results that may be expected for a full year. These financial statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. |
Excise Taxes | Excise taxes are levied on Ameren Missouriās electric and natural gas businesses and on Ameren Illinoisā natural gas business and are recorded gross in āOperating Revenues - Electric,ā āOperating Revenues - Gasā and āOperating Expenses - Taxes other than income taxesā on the statement of income or the statement of income and comprehensive income. Excise taxes for electric service in Illinois are levied on the customer and are therefore not included in Ameren Illinoisā revenues and expenses. |
Uncertain Tax Positions | It is reasonably possible that events will occur during the next 12 months that would cause the total amount of our unrecognized tax benefits to fluctuate. We do not believe any such fluctuations would be material to our results of operations, financial position, or liquidity. State income tax returns are generally subject to examination for a period of three years after filing. We do not currently have material state income tax issues under examination, administrative appeal, or litigation. The state impact of any federal changes remains subject to examination by various states for a period of up to one year after formal notification to the states. |
Accounting and Reporting Developments | Below is a summary of recently issued authoritative accounting standards relevant to the Ameren Companies. Revenue from Contracts with Customers In 2014, FASB issued authoritative accounting guidance to clarify the principles for recognizing revenue and to develop a common revenue standard for GAAP. The guidance requires an entity to recognize an amount of revenue for the transfer of promised goods or services to customers that reflects the consideration which 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. In July 2015, FASB deferred the effective date of the new revenue standard to the first quarter of 2018. The guidance allows entities to choose one of two transition methods, either by applying the guidance retrospectively to each reporting period presented or 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 positions and disclosures, as well as the transition method that they will use to adopt the guidance. Presentation of Debt Issuance Costs In April 2015, FASB issued authoritative accounting guidance to simplify the presentation of debt issuance costs. The guidance requires debt issuance costs to be presented in the balance sheet as a reduction to the associated debt liability. Currently, debt issuance costs are presented as a component of āOther assetsā on the Ameren Companiesā balance sheets. As of June 30, 2015, Ameren, Ameren Missouri, and Ameren Illinois had debt issuance costs of $36 million , $20 million , and $16 million , respectively. The guidance will be effective for the Ameren Companies in the first quarter of 2016 and applied retrospectively, and it will not affect the Ameren Companies' results of operations or cash flows. |
Derivative Financial Instrume23
Derivative Financial Instruments Derivative Financial Instruments (Policies) | 6 Months Ended |
Jun. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivatives | ā¢ 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; ā¢ market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; and ā¢ 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. |
Retirement Benefits Retirement
Retirement Benefits Retirement Benefits (Policies) | 6 Months Ended |
Jun. 30, 2015 | |
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract] | |
Retirement Benefits | Amerenās pension plans are funded in compliance with income tax regulations and to meet federal funding or regulatory requirements. As a result, Ameren expects to fund its pension plans at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering Amerenās assumptions at June 30, 2015 , the planās estimated investment performance through June 30, 2015 , and Amerenās pension funding policy, Ameren expects to make annual contributions of $25 million to $115 million through 2019, with aggregate estimated contributions of $290 million . These amounts are estimates which may change with actual investment performance, changes in interest rates, any pertinent changes in government regulations, and any voluntary contributions. Separately, our policy for postretirement benefits is primarily to fund the voluntary employeesā beneficiary association trusts to match the annual postretirement expense. |
Summary Of Significant Accoun25
Summary Of Significant Accounting Policies (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Accounting Policies [Abstract] | |
Schedule of Change in Asset Retirement Obligation | The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the six months ended June 30, 2015 : Ameren Missouri Ameren Illinois (a) Ameren Balance at December 31, 2014 $ 389 $ 7 $ 396 Accretion in 2015 (b) 11 (c) 11 Change in estimates (d) 182 (c) 182 Balance at June 30, 2015 $ 582 $ 7 $ 589 (a) Included in āOther deferred credits and liabilitiesā on the balance sheet. (b) Accretion expense was recorded as an increase to regulatory assets. (c) Less than $1 million. (d) The ARO increase resulted in a corresponding increase recorded to āProperty and Plant, Net.ā During the first quarter of 2015, 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, 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, during the second quarter of 2015, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $79 million to their AROs associated with CCR storage facilities. See Note 9 - Commitments and Contingencies for additional information. Also during the second quarter of 2015, Ameren and Ameren Missouri 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 MoPSCās April 2015 electric rate order. |
Summary Of Nonvested Shares Related To Long-Term Incentive Plan | A summary of nonvested performance share units at June 30, 2015 , and changes during the six months ended June 30, 2015 , under the 2006 Incentive Plan and the 2014 Incentive Plan are presented below: Number of Performance Share Units Weighted-average Fair Value Per Performance Share Unit Nonvested at January 1, 2015 1,162,377 $ 35.35 Granted (a) 567,240 52.88 Forfeitures (1,944 ) 34.75 Vested (b) (85,694 ) 46.79 Nonvested at June 30, 2015 1,641,979 $ 40.81 (a) Performance share units granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. (b) Performance share units vested due to the 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. |
Schedule of Unrecognized Tax Benefits | The following table presents the total amount of reserves for unrecognized tax benefits (detriments) related to uncertain tax positions as of June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Ameren $ ā $ 54 Ameren Missouri ā ā Ameren Illinois ā (1 ) |
Schedule of Unrecognized Tax Benefits That Would Impact Effective Tax Rate | The following table presents the amount of reserves for unrecognized tax benefits, included in the table above, related to uncertain tax positions that, if recognized, would have impacted results of operations as of December 31, 2014 : December 31, 2014 Ameren $ 52 Ameren Missouri ā Ameren Illinois (1 ) |
Schedule of Excise Taxes | The following table presents excise taxes recorded in āOperating Revenues - Electric,ā āOperating Revenues - Gasā and āOperating Expenses - Taxes other than income taxesā for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Ameren Missouri $ 41 $ 39 $ 75 $ 73 Ameren Illinois 10 11 33 37 Ameren $ 51 $ 50 $ 108 $ 110 |
Short-Term Debt And Liquidity S
Short-Term Debt And Liquidity Short-Term Debt and Liquidity (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Schedule of Commercial paper [Abstract] | |
Schedule of Short-term Debt | The following table presents commercial paper outstanding at Ameren (parent), Ameren Missouri, and Ameren Illinois as of June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Ameren (parent) $ 836 $ 585 Ameren Missouri 38 97 Ameren Illinois 12 32 Ameren Consolidated $ 886 $ 714 The following table summarizes the borrowing activity and relevant interest rates under Amerenās (parent), Ameren Missouriās, and Ameren Illinoisā commercial paper programs for the six months ended June 30, 2015 and 2014: Ameren (parent) Ameren Missouri Ameren Illinois Ameren Consolidated 2015 Average daily commercial paper outstanding $ 754 $ 84 $ 5 $ 843 Weighted-average interest rate 0.57 % 0.50 % 0.44 % 0.56 % Peak commercial paper during period (a) $ 849 $ 294 $ 39 $ 1,108 Peak interest rate 0.70 % 0.60 % 0.60 % 0.70 % 2014 Average daily commercial paper outstanding $ 328 $ 146 $ 242 $ 607 Weighted-average interest rate 0.32 % 0.31 % 0.32 % 0.32 % Peak commercial paper during period (a) $ 503 $ 495 $ 300 $ 907 Peak interest rate 0.35 % 0.70 % 0.34 % 0.70 % (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 Fin27
Long-Term Debt And Equity Financings (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Long-Term Debt And Equity Financings [Line Items] | |
Schedule Of Coverage Ratios | Indenture Provisions and Other Covenants Ameren Missouriās and Ameren Illinoisā 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 companiesā ability to issue bonds or preferred stock. The following table summarizes the required and actual interest coverage ratios, and dividend coverage ratios, and bonds and preferred stock issuable as of June 30, 2015 , at an assumed annual 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 ā„2.0 3.5 $ 3,305 ā„2.5 94.4 $ 2,095 Ameren Illinois ā„2.0 6.7 3,533 (d) ā„1.5 2.8 203 (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 companyās 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 2012 Illinois Credit Agreement. (e) Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinoisā articles of incorporation. |
Other Income and Expenses (Tabl
Other Income and Expenses (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Other Nonoperating Income (Expense) [Abstract] | |
Other Income And Expenses | The following table presents the components of āOther Income and Expensesā in the Ameren Companiesā statements of income for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Ameren: (a) Miscellaneous income: Allowance for equity funds used during construction $ 6 $ 9 $ 11 $ 16 Interest income on industrial development revenue bonds 6 7 13 14 Interest income 4 2 8 5 Other ā 3 3 4 Total miscellaneous income $ 16 $ 21 $ 35 $ 39 Miscellaneous expense: Donations $ 2 $ 1 $ 10 $ 6 Other 4 3 7 7 Total miscellaneous expense $ 6 $ 4 $ 17 $ 13 Ameren Missouri: Miscellaneous income: Allowance for equity funds used during construction $ 5 $ 8 $ 9 $ 15 Interest income on industrial development revenue bonds 6 7 13 14 Interest income 1 1 1 1 Total miscellaneous income $ 12 $ 16 $ 23 $ 30 Miscellaneous expense: Donations $ 1 $ 1 $ 3 $ 3 Other 1 1 2 3 Total miscellaneous expense $ 2 $ 2 $ 5 $ 6 Ameren Illinois: Miscellaneous income: Allowance for equity funds used during construction $ 1 $ 1 $ 2 $ 1 Interest income 3 1 7 3 Other ā 3 2 4 Total miscellaneous income $ 4 $ 5 $ 11 $ 8 Miscellaneous expense: Donations $ 1 $ ā $ 4 $ 3 Other 1 1 3 2 Total miscellaneous expense $ 2 $ 1 $ 7 $ 5 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Derivative Financial Instrume29
Derivative Financial Instruments (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosure [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 June 30, 2015 , and December 31, 2014 . As of June 30, 2015 , these contracts ran through October 2017, March 2021, May 2032, and December 2016 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) 39 (b) 39 50 (b) 50 Natural gas (in mmbtu) 29 127 156 28 108 136 Power (in megawatthours) 1 10 11 1 11 12 Uranium (pounds in thousands) 316 (b) 316 332 (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 instruments, none of which were designated as hedging instruments, as of June 30, 2015 , and December 31, 2014 : Balance Sheet Location Ameren Missouri Ameren Illinois Ameren 2015 Fuel oils Other current assets $ 1 $ ā $ 1 Natural gas Other assets ā 1 1 Power Other current assets 29 ā 29 Total assets $ 30 $ 1 $ 31 Fuel oils Other current liabilities $ 14 $ ā $ 14 Other deferred credits and liabilities 5 ā 5 Natural gas MTM derivative liabilities (a) 24 (a) Other current liabilities 4 ā 28 Other deferred credits and liabilities 7 14 21 Power MTM derivative liabilities (a) 11 (a) Other current liabilities 2 ā 13 Other deferred credits and liabilities ā 154 154 Uranium Other current liabilities 2 ā 2 Total liabilities $ 34 $ 203 $ 237 2014 Fuel oils Other current assets $ 2 $ ā $ 2 Natural gas Other current assets 1 1 2 Power Other current assets 15 ā 15 Total assets $ 18 $ 1 $ 19 Fuel oils Other current liabilities $ 22 $ ā $ 22 Other deferred credits and liabilities 7 ā 7 Natural gas MTM derivative liabilities (a) 31 (a) Other current liabilities 6 ā 37 Other deferred credits and liabilities 6 13 19 Power MTM derivative liabilities (a) 11 (a) Other current liabilities 3 ā 14 Other deferred credits and liabilities ā 131 131 Uranium Other current liabilities 2 ā 2 Total liabilities $ 46 $ 186 $ 232 (a) Balance sheet line item not applicable to registrant. |
Cumulative Pretax Net Gains (Losses) On All Derivative Instruments In OCI | The following table presents the cumulative amount of pretax net gains (losses) on all derivative instruments deferred in regulatory assets or regulatory liabilities as of June 30, 2015 , and December 31, 2014 : Ameren Missouri Ameren Illinois Ameren 2015 Fuel oils derivative contracts (a) $ (19 ) $ ā $ (19 ) Natural gas derivative contracts (b) (11 ) (37 ) (48 ) Power derivative contracts (c) 27 (165 ) (138 ) Uranium derivative contracts (d) (2 ) ā (2 ) 2014 Fuel oils derivative contracts $ (29 ) $ ā $ (29 ) Natural gas derivative contracts (11 ) (43 ) (54 ) Power derivative contracts 12 (142 ) (130 ) Uranium derivative contracts (2 ) ā (2 ) (a) Represents net losses associated with fuel oils derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās rail transportation surcharges for coal through December 2017. Current gains deferred as regulatory liabilities include $1 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $14 million at Ameren and Ameren Missouri. (b) Represents net losses associated with natural gas derivative contracts. These contracts are a partial hedge of natural gas requirements through March 2021 at Ameren and Ameren Missouri and through October 2018 at Ameren Illinois. Current losses deferred as regulatory assets include $28 million , $4 million , and $24 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. (c) Represents net gains (losses) associated with power derivative contracts. These contracts are a partial hedge of power price requirements through May 2032 at Ameren and Ameren Illinois and through December 2016 at Ameren Missouri. Current gains deferred as regulatory liabilities include $29 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $13 million , $2 million , and $11 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. (d) Represents net losses on uranium derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās uranium requirements through January 2017. Current losses deferred as regulatory assets include $2 million at Ameren and Ameren Missouri. Der |
Offsetting Derivative Assets and Liabilities | 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 June 30, 2015 , and December 31, 2014 : Gross Amounts Not Offset in the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount 2015 Assets: Ameren Missouri $ 30 $ 3 $ ā $ 27 Ameren Illinois 1 ā ā 1 Ameren $ 31 $ 3 $ ā $ 28 Liabilities: Ameren Missouri $ 34 $ 3 $ 2 $ 29 Ameren Illinois 203 ā ā 203 Ameren $ 237 $ 3 $ 2 $ 232 2014 Assets: Ameren Missouri $ 18 $ 5 $ ā $ 13 Ameren Illinois 1 ā ā 1 Ameren $ 19 $ 5 $ ā $ 14 Liabilities: Ameren Missouri $ 46 $ 5 $ 5 $ 36 Ameren Illinois 186 ā ā 186 Ameren $ 232 $ 5 $ 5 $ 222 (a) Cash collateral received reduces gross asset balances and is included in āOther current liabilitiesā and āOther deferred credits and liabilitiesā on the balance sheet. Cash collateral posted reduces gross liability balances and is included in āOther current assetsā and āOther assetsā on the balance sheet. |
Derivative Instruments With Credit Risk-Related Contingent Features | 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 June 30, 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 $ 80 $ 3 $ 73 Ameren Illinois 77 ā 72 Ameren $ 157 $ 3 $ 145 (a) Prior to 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 (Tables
Fair Value Measurements (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Fair Value Disclosures [Abstract] | |
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Valuation Techniques | The following table describes the valuation techniques and unobservable inputs for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of June 30, 2015 : Fair Value Weighted Average Assets Liabilities Valuation Technique(s) Unobservable Input Range Level 3 Derivative asset and liability - commodity contracts (a) : Ameren Fuel oils $ 1 $ (2 ) Option model Volatilities(%) (b) 32 - 50 37 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.40 (d) Natural gas ā (1 ) Discounted cash flow Nodal basis($/mmbtu) (e) (0.60) - 0 (0.40) Counterparty credit risk(%) (b)(c) 0.21 - 2.01 0.83 Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Power (f) 29 (167 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (g) 26 - 45 31 Estimated auction price for FTRs($/MW) (e) (1,006) - 1,606 184 Nodal basis($/MWh) (e) (11) - (1) (3) Counterparty credit risk(%) (b)(c) 0.39 - 13.86 8.64 Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 3 - 6 4 Escalation rate(%) (e)(h) 2 (d) Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 36 - 39 37 Ameren Missouri Fuel oils $ 1 $ (2 ) Option model Volatilities(%) (b) 32 - 50 37 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.40 (d) Power (f) 29 (2 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (b) 26 - 45 34 Estimated auction price for FTRs($/MW) (e) (1,006) - 1,606 184 Nodal basis($/MWh) (b) (11) - (4) (9) Counterparty credit risk(%) (b)(c) 0.39 - 13.86 8.64 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 36 - 39 37 Ameren Illinois Natural gas $ ā $ (1 ) Discounted cash flow Nodal basis($/mmbtu) (e) (0.60) - 0 (0.40) Counterparty credit risk(%) (b)(c) 0.21 - 2.01 0.83 Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Power (f) ā (165 ) Discounted cash flow Average forward peak and off-peak pricing - forwards/swaps($/MWh) (e) 27 - 37 30 Nodal basis($/MWh) (e) (6) - (1) (3) Ameren Illinois credit risk(%) (b)(c) 0.40 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 3 - 6 4 Escalation rate(%) (e)(h) 2 (d) Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 (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 lower (higher) fair value measurement. (c) 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. (d) Not applicable. (e) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (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 due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. (h) Escalation rate applies to power prices 2026 and beyond. The following table describes the valuation techniques and unobservable inputs for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of December 31, 2014 : Fair Value Weighted Assets Liabilities Valuation Technique(s) Unobservable Input Range Average Level 3 Derivative asset and liability ā commodity contracts (a) : Ameren Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (b) 3 - 39 32 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Escalation rate(%) (e)(f) 5 (d) Natural Gas 1 (2 ) Option model Volatilities(%) (b) 31 - 144 63 Nodal basis($/mmbtu) (e) (0.40) - 0 (0.20) Discounted cash flow Nodal basis($/mmbtu) (e) (0.40) - 0.10 (0.20) Counterparty credit risk(%) (b)(c) 0.43 - 13 3 Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Power (g) 11 (144 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (h) 27 - 50 32 Estimated auction price for FTRs($/MW) (e) (1,833) - 2,743 171 Nodal basis($/MWh) (e) (6) - 0 (2) Counterparty credit risk(%) (b)(c) 0.26 (d) Ameren Missouri and Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 4 - 5 4 Escalation rate(%) (e)(i) 0 - 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 35 - 40 36 Ameren Missouri Fuel oils $ 2 $ (8 ) Option model Volatilities(%) (b) 3 - 39 32 Discounted cash flow Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Escalation rate(%) (e)(f) 5 (d) Natural Gas ā (1 ) Option model Volatilities(%) (b) 31 - 144 53 Nodal basis($/mmbtu) (e) (0.40) - 0 (0.30) Discounted cash flow Nodal basis($/mmbtu) (e) (0.10) (d) Counterparty credit risk(%) (b)(c) 0.57 - 13 5 Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Power (g) 11 (2 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (b) 27 - 50 32 Estimated auction price for FTRs($/MW) (e) (1,833) - 2,743 171 Counterparty credit risk(%) (b)(c) 0.26 (d) Ameren Missouri credit risk(%) (b)(c) 0.43 (d) Uranium ā (2 ) Discounted cash flow Average forward uranium pricing($/pound) (e) 35 - 40 36 Ameren Illinois Natural Gas $ 1 $ (1 ) Option model Volatilities(%) (b) 50 - 144 94 Nodal basis($/mmbtu) (e) (0.10) - 0 (0.10) Discounted cash flow Nodal basis($/mmbtu) (e) (0.40) - 0.10 (0.20) Counterparty credit risk(%) (b)(c) 0.43 - 2 0.83 Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Power (g) ā (142 ) Discounted cash flow Average forward peak and off-peak pricing ā forwards/swaps($/MWh) (e) 27 - 38 32 Nodal basis($/MWh) (e) (6) - 0 (2) Ameren Illinois credit risk(%) (b)(c) 0.43 (d) Fundamental energy production model Estimated future gas prices($/mmbtu) (e) 4 - 5 4 Escalation rate(%) (e)(i) 0 - 1 1 Contract price allocation Estimated renewable energy credit costs($/credit) (e) 5 - 7 6 (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 lower (higher) fair value measurement. (c) 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. (d) Not applicable. (e) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (f) Escalation rate applies to fuel oil prices 2017 and beyond. (g) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2018. Valuations beyond 2018 use fundamentally modeled pricing by month for peak and off-peak demand. (h) The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. (i) Escalation rate applies to power prices 2026 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 June 30, 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) : Fuel oils $ ā $ ā $ 1 $ 1 Natural gas ā 1 ā 1 Power ā ā 29 29 Total derivative assets - commodity contracts $ ā $ 1 $ 30 $ 31 Nuclear decommissioning trust fund: Cash and cash equivalents $ 6 $ ā $ ā $ 6 Equity securities: U.S. large capitalization 370 ā ā 370 Debt securities: Corporate bonds ā 59 ā 59 U.S. treasury and agency securities ā 100 ā 100 Other ā 22 ā 22 Total nuclear decommissioning trust fund $ 376 $ 181 $ ā $ 557 (b) Total Ameren $ 376 $ 182 $ 30 $ 588 Ameren Derivative assets - commodity contracts (a) : Missouri Fuel oils $ ā $ ā $ 1 $ 1 Power ā ā 29 29 Total derivative assets - commodity contracts $ ā $ ā $ 30 $ 30 Nuclear decommissioning trust fund: Cash and cash equivalents $ 6 $ ā $ ā $ 6 Equity securities: U.S. large capitalization 370 ā ā 370 Debt securities: Corporate bonds ā 59 ā 59 U.S. treasury and agency securities ā 100 ā 100 Other ā 22 ā 22 Total nuclear decommissioning trust fund $ 376 $ 181 $ ā $ 557 (b) Total Ameren Missouri $ 376 $ 181 $ 30 $ 587 Ameren Derivative assets - commodity contracts (a) : Illinois Natural gas $ ā $ 1 $ ā $ 1 Liabilities: Ameren Derivative liabilities - commodity contracts (a) : Fuel oils $ 17 $ ā $ 2 $ 19 Natural gas ā 48 1 49 Power ā ā 167 167 Uranium ā ā 2 2 Total Ameren $ 17 $ 48 $ 172 $ 237 Ameren Derivative liabilities - commodity contracts (a) : Missouri Fuel oils $ 17 $ ā $ 2 $ 19 Natural gas ā 11 ā 11 Power ā ā 2 2 Uranium ā ā 2 2 Total Ameren Missouri $ 17 $ 11 $ 6 $ 34 Ameren Derivative liabilities - commodity contracts (a) : Illinois Natural gas $ ā $ 37 $ 1 $ 38 Power ā ā 165 165 Total Ameren Illinois $ ā $ 37 $ 166 $ 203 (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 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 $ ā $ ā $ 2 $ 2 Natural gas ā 1 1 2 Power ā 4 11 15 Total derivative assets - commodity contracts $ ā $ 5 $ 14 $ 19 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ ā $ ā $ 1 Equity securities: U.S. large capitalization 364 ā ā 364 Debt securities: Corporate bonds ā 63 ā 63 U.S. treasury and agency securities ā 102 ā 102 Other ā 17 ā 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ ā $ 547 (b) Total Ameren $ 365 $ 187 $ 14 $ 566 Ameren Derivative assets - commodity contracts (a) : Missouri Fuel oils $ ā $ ā $ 2 $ 2 Natural gas ā 1 ā 1 Power ā 4 11 15 Total derivative assets - commodity contracts $ ā $ 5 $ 13 $ 18 Nuclear decommissioning trust fund: Cash and cash equivalents $ 1 $ ā $ ā $ 1 Equity securities: U.S. large capitalization 364 ā ā 364 Debt securities: Corporate bonds ā 63 ā 63 U.S. treasury and agency securities ā 102 ā 102 Other ā 17 ā 17 Total nuclear decommissioning trust fund $ 365 $ 182 $ ā $ 547 (b) Total Ameren Missouri $ 365 $ 187 $ 13 $ 565 Ameren Derivative assets - commodity contracts (a) : Illinois Natural gas $ ā $ ā $ 1 $ 1 Liabilities: Ameren Derivative liabilities - commodity contracts (a) : Fuel oils $ 21 $ ā $ 8 $ 29 Natural gas 1 53 2 56 Power ā 1 144 145 Uranium ā ā 2 2 Total Ameren $ 22 $ 54 $ 156 $ 232 Ameren Derivative liabilities - commodity contracts (a) : Missouri Fuel oils $ 21 $ ā $ 8 $ 29 Natural gas 1 10 1 12 Power ā 1 2 3 Uranium ā ā 2 2 Total Ameren Missouri $ 22 $ 11 $ 13 $ 46 Ameren Derivative liabilities - commodity contracts (a) : Illinois Natural gas $ ā $ 43 $ 1 $ 44 Power ā ā 142 142 Total Ameren Illinois $ ā $ 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 Three 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 three months ended June 30, 2015 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at April 1, 2015 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities 1 (a) 1 Settlements 2 (a) 2 Transfers out of Level 3 2 (a) 2 Ending balance at June 30, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ 3 $ (a) $ 3 Natural gas: Beginning balance at April 1, 2015 $ (1 ) $ 1 $ ā Purchases ā (1 ) (1 ) Settlements 1 (1 ) ā Ending balance at June 30, 2015 $ ā $ (1 ) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ ā $ ā Power: Beginning balance at April 1, 2015 $ 4 $ (164 ) $ (160 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities ā (4 ) (4 ) Purchases 29 ā 29 Settlements (6 ) 3 (3 ) Ending balance at June 30, 2015 $ 27 $ (165 ) $ (138 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ 1 $ (5 ) $ (4 ) Uranium: Beginning balance at April 1, 2015 $ (1 ) $ (a) $ (1 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (1 ) (a) (1 ) Ending balance at June 30, 2015 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ (1 ) $ (a) $ (1 ) (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 three months ended June 30, 2014 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at April 1, 2014 $ 1 $ (a) $ 1 Realized and unrealized gains (losses) included in regulatory assets/liabilities 1 (a) 1 Ending balance at June 30, 2014 $ 2 $ (a) $ 2 Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ 1 $ (a) $ 1 Natural gas: Beginning balance at April 1, 2014 $ ā $ ā $ ā Purchases ā 1 1 Settlements ā (1 ) (1 ) Ending balance at June 30, 2014 $ ā $ ā $ ā Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ ā $ ā Power: Beginning balance at April 1, 2014 $ 10 $ (120 ) $ (110 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (13 ) 16 3 Purchases 34 ā 34 Settlements (15 ) 1 (14 ) Transfers out of Level 3 (1 ) ā (1 ) Ending balance at June 30, 2014 $ 15 $ (103 ) $ (88 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (1 ) $ 15 $ 14 Uranium: Beginning balance at April 1, 2014 $ (5 ) $ (a) $ (5 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (4 ) (a) (4 ) Settlements 2 (a) 2 Ending balance at June 30, 2014 $ (7 ) $ (a) $ (7 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (4 ) $ (a) $ (4 ) (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 six months ended June 30, 2015 : Net derivative commodity contracts Ameren Missouri Ameren Illinois Ameren Fuel oils: Beginning balance at January 1, 2015 $ (6 ) $ (a) $ (6 ) Settlements 3 (a) 3 Transfers out of Level 3 2 (a) 2 Ending balance at June 30, 2015 $ (1 ) $ (a) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (a) $ ā Natural gas: Beginning balance at January 1, 2015 $ (1 ) $ ā $ (1 ) Settlements 1 (1 ) ā Ending balance at June 30, 2015 $ ā $ (1 ) $ (1 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ ā $ ā Power: Beginning balance at January 1, 2015 $ 9 $ (142 ) $ (133 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (2 ) (29 ) (31 ) Purchases 29 ā 29 Settlements (9 ) 6 (3 ) Ending balance at June 30, 2015 $ 27 $ (165 ) $ (138 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (29 ) $ (29 ) Uranium: Beginning balance at January 1, 2015 $ (2 ) $ (a) $ (2 ) Ending balance at June 30, 2015 $ (2 ) $ (a) $ (2 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2015 $ ā $ (a) $ ā (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 six months ended June 30, 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 (1 ) (a) (1 ) Settlements (2 ) (a) (2 ) Ending balance at June 30, 2014 $ 2 $ (a) $ 2 Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ (a) $ ā Natural gas: Beginning balance at January 1, 2014 $ ā $ ā $ ā Purchases ā (1 ) (1 ) Settlements ā 1 1 Ending balance at June 30, 2014 $ ā $ ā $ ā Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ ā $ ā $ ā Power: Beginning balance at January 1, 2014 $ 19 $ (108 ) $ (89 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (18 ) 4 (14 ) Purchases 34 ā 34 Settlements (20 ) 1 (19 ) Ending balance at June 30, 2014 $ 15 $ (103 ) $ (88 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (3 ) $ 1 $ (2 ) Uranium: Beginning balance at January 1, 2014 $ (6 ) $ (a) $ (6 ) Realized and unrealized gains (losses) included in regulatory assets/liabilities (4 ) (a) (4 ) Settlements 3 (a) 3 Ending balance at June 30, 2014 $ (7 ) $ (a) $ (7 ) Change in unrealized gains (losses) related to assets/liabilities held at June 30, 2014 $ (4 ) $ (a) $ (4 ) (a) Not applicable. |
Schedule Of Transfers Between Fair Value Hierarchy Levels | The following table summarizes all transfers between fair value hierarchy levels related to derivative commodity contracts for the three and six months ended June 30, 2015 , and 2014 : 2015 2014 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Three Months Transfers out of Level 3 / Transfers into Level 1 - Fuel oils $ 2 $ ā $ 2 $ ā $ ā $ ā Transfers out of Level 3 / Transfers into Level 2 - Power ā ā ā (1 ) ā (1 ) Six Months Transfers out of Level 3 / Transfers into Level 1 - Fuel oils $ 2 $ ā $ 2 $ ā $ ā $ ā |
Schedule Of Carrying Amounts And Estimated Fair Values Of Long-Term Debt, Capital Lease Obligations And Preferred Stock | The following table presents the carrying amounts and estimated fair values of our long-term debt, capital lease obligations and preferred stock at June 30, 2015 , and December 31, 2014 : June 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Ameren: (a) Long-term debt and capital lease obligations (including current portion) $ 6,376 $ 6,919 $ 6,240 $ 7,135 Preferred stock 142 122 142 122 Ameren Missouri: Long-term debt and capital lease obligations (including current portion) $ 4,135 $ 4,492 $ 3,999 $ 4,518 Preferred stock 80 73 80 73 Ameren Illinois: Long-term debt $ 2,241 $ 2,427 $ 2,241 $ 2,517 Preferred stock 62 49 62 49 (a) Preferred stock is recorded in āNoncontrolling Interestsā on the consolidated balance sheet. |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 6 Months Ended |
Jun. 30, 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 three and six months ended June 30, 2015 and 2014 . Three Months Six Months Agreement Income Statement Line Item Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Ameren Missouri power supply Operating Revenues 2015 $ 4 $ (a) $ 5 $ (a) agreements with Ameren Illinois 2014 3 (a) 3 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2015 7 1 13 2 rent and facility services 2014 4 1 9 1 Ameren Missouri and Ameren Illinois Operating Revenues 2015 1 (b) 1 (b) miscellaneous support services 2014 1 (b) 1 (b) Total Operating Revenues 2015 $ 12 $ 1 $ 19 $ 2 2014 8 1 13 1 Ameren Illinois power supply Purchased Power 2015 $ (a) $ 4 $ (a) $ 5 agreements with Ameren Missouri 2014 (a) 3 (a) 3 Ameren Illinois transmission Purchased Power 2015 (a) (b) (a) 1 services with ATXI 2014 (a) (b) (a) 1 Total Purchased Power 2015 $ (a) $ 4 $ (a) $ 6 2014 (a) 3 (a) 4 Ameren Services support services Other Operations and Maintenance 2015 $ 32 $ 30 $ 66 $ 59 agreement 2014 32 27 65 54 Money pool borrowings (advances) Interest Charges/ Miscellaneous Income 2015 $ (b) $ (b) $ (b) $ (b) 2014 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies (
Commitments And Contingencies (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of Insurance Coverage at Callaway Energy Center | The following table presents insurance coverage at Ameren Missouriās Callaway energy center at June 30, 2015 . The property coverage and the nuclear liability coverage must be renewed on April 1 and January 1, respectively, of each year. Both coverages were renewed in 2015. Type and Source of Coverage Maximum Coverages Maximum Assessments for Single Incidents Public liability and nuclear worker liability: American Nuclear Insurers $ 375 $ ā Pool participation 12,986 (a) 128 (b) $ 13,361 (c) $ 128 Property damage: NEIL $ 2,750 (d) $ 27 (e) European Mutual Association for Nuclear Insurance 500 (f) ā $ 3,250 $ 27 Replacement power: NEIL $ 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 $128 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 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 Asbestors-Related Litigation Pending Lawsuits | The following table presents the pending asbestos-related lawsuits filed against the Ameren Companies as of June 30, 2015 : Ameren Ameren Missouri Ameren Illinois Total (a) 1 28 36 49 (a) Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract] | |
Components Of Net Periodic Benefit Cost | The following table presents the components of the net periodic benefit cost (benefit) incurred for Amerenās pension and postretirement benefit plans for the three and six months ended June 30, 2015 and 2014 : Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $ 22 $ 19 $ 46 $ 40 $ 6 $ 4 $ 11 $ 9 Interest cost 43 42 87 91 12 12 24 25 Expected return on plan assets (62 ) (57 ) (124 ) (114 ) (17 ) (16 ) (34 ) (32 ) Amortization of: Prior service benefit ā ā ā ā (1 ) (1 ) (2 ) (2 ) Actuarial loss (gain) 19 12 37 24 2 (2 ) 3 (3 ) Settlement loss 1 ā 1 ā ā ā ā ā Net periodic benefit cost (benefit) $ 23 $ 16 $ 47 $ 41 $ 2 $ (3 ) $ 2 $ (3 ) |
Summary Of Benefit Plan Costs Incurred | Ameren Missouri and Ameren Illinois are responsible for their respective shares of Amerenās pension and postretirement costs. The following table presents the pension costs and the postretirement benefit costs (benefit) incurred for the three and six months ended June 30, 2015 and 2014 : Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Ameren Missouri $ 13 $ 8 $ 28 $ 25 $ 3 $ 1 $ 4 $ 2 Ameren Illinois 10 7 19 15 (1 ) (3 ) (2 ) (4 ) Other ā 1 ā 1 ā (1 ) ā (1 ) Ameren (a) $ 23 $ 16 $ 47 $ 41 $ 2 $ (3 ) $ 2 $ (3 ) (a) Includes amounts for Ameren registrants and nonregistrant subsidiaries. |
Divestiture Transactions and 34
Divestiture Transactions and Discontinued Operations Divestiture Transactions and Discontinued Operations (Tables) | 6 Months Ended |
Jun. 30, 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 for the three and six months ended June 30, 2015 and 2014 : Three Months Six Months 2015 2014 2015 2014 Operating revenues $ ā $ ā $ ā $ 1 Operating benefits (expenses) ā (1 ) 3 (3 ) Operating income (loss) before income tax ā (1 ) 3 (2 ) Income tax benefit 52 ā 49 ā Income (loss) from discontinued operations, net of taxes $ 52 $ (1 ) $ 52 $ (2 ) The following table presents the carrying amounts of the components of assets and liabilities of Amerenās discontinued operations, which consist primarily of AROs and related deferred income tax assets associated with the abandoned Meredosia and Hutsonville energy centers, at June 30, 2015 , and December 31, 2014: June 30, 2015 December 31, 2014 Assets of discontinued operations Accumulated deferred income taxes, net $ 15 $ 15 Total assets of discontinued operations $ 15 $ 15 Liabilities of discontinued operations Accounts payable and other current obligations $ 2 $ 1 Asset retirement obligations 30 32 Total liabilities of discontinued operations $ 32 $ 33 |
Segment Information (Tables)
Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Segment Reporting [Abstract] | |
Schedule Of Segment Reporting Information By Segment | The following table presents information about the reported revenues and net income attributable to Ameren Corporation from continuing operations for the three and six months ended June 30, 2015 and 2014 , and total assets of continuing operations as of June 30, 2015 , and December 31, 2014 : Three Months Ameren Missouri Ameren Illinois Other Intersegment Eliminations Ameren 2015 External revenues $ 872 $ 512 $ 17 $ ā $ 1,401 Intersegment revenues 12 1 ā (13 ) ā Net income attributable to Ameren Corporation from continuing operations 61 31 6 ā 98 2014 External revenues $ 893 $ 518 $ 8 $ ā $ 1,419 Intersegment revenues 7 1 ā (8 ) ā Net income (loss) attributable to Ameren Corporation from continuing operations 126 28 (4 ) ā 150 Six Months 2015 External revenues $ 1,665 $ 1,256 $ 36 $ ā $ 2,957 Intersegment revenues 19 2 1 (22 ) ā Net income attributable to Ameren Corporation from continuing operations 102 84 20 ā 206 2014 External revenues $ 1,704 $ 1,292 $ 17 $ ā $ 3,013 Intersegment revenues 13 1 1 (15 ) ā Net income (loss) attributable to Ameren Corporation from continuing operations 173 81 (7 ) ā 247 As of June 30, 2015: Total assets $ 13,721 $ 8,500 $ 1,036 $ (120 ) $ 23,137 (a) As of December 31, 2014: Total assets $ 13,541 $ 8,381 $ 942 $ (203 ) $ 22,661 (a) (a) Excludes total assets from discontinued operations of $15 million as of June 30, 2015 , and December 31, 2014. |
Summary Of Significant Accoun36
Summary Of Significant Accounting Policies (Narrative) (Detail) $ in Millions | Jun. 30, 2015USD ($) |
Basis Of Presentation And Significant Accounting Policies [Line Items] | |
Debt Issuance Cost | $ 36 |
Union Electric Company | |
Basis Of Presentation And Significant Accounting Policies [Line Items] | |
Debt Issuance Cost | 20 |
Ameren Illinois Company | |
Basis Of Presentation And Significant Accounting Policies [Line Items] | |
Debt Issuance Cost | $ 16 |
Summary Of Significant Accoun37
Summary Of Significant Accounting Policies Summary of Significant Accounting Policies (Schedule of Asset Retirement Obligations) (Details) - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Dec. 31, 2014 | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | $ 589 | $ 396 | |
Asset Retirement Obligation, Accretion Expense | [1] | 11 | |
Asset Retirement Obligation, Revision of Estimate | [2] | 182 | |
Union Electric Company | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 582 | 389 | |
Asset Retirement Obligation, Accretion Expense | [1] | 11 | |
Asset Retirement Obligation, Revision of Estimate | [2] | 182 | |
Ameren Illinois Company | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | [3] | 7 | $ 7 |
Asset Retirement Obligation, Accretion Expense | [1],[4] | 1 | |
Asset Retirement Obligation, Revision of Estimate | [2],[4] | 1 | |
Callaway energy center decommissioning study | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | 99 | ||
Callaway energy center decommissioning study | Union Electric Company | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | 99 | ||
New CCR Rules Estimate | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | 79 | ||
New CCR Rules Estimate | Union Electric Company | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | 79 | ||
Other Estimate Changes | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | 4 | ||
Other Estimate Changes | Union Electric Company | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation, Revision of Estimate | $ 4 | ||
[1] | Accretion expense was recorded as an increase to regulatory assets. | ||
[2] | The ARO increase resulted in a corresponding increase recorded to āProperty and Plant, Net.ā During the first quarter of 2015, 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, 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, during the second quarter of 2015, as a result of new federal regulations, Ameren and Ameren Missouri recorded an increase of $79 million to their AROs associated with CCR storage facilities. See Note 9 - Commitments and Contingencies for additional information. Also during the second quarter of 2015, Ameren and Ameren Missouri 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 MoPSCās April 2015 electric rate order. | ||
[3] | Included in āOther deferred credits and liabilitiesā on the balance sheet | ||
[4] | Less than $1 million. |
Summary Of Significant Accoun38
Summary Of Significant Accounting Policies Summary of Significant Accounting Policies (Summary of Nonvested Shares Related To Long-Term Incentive Plan) (Details) - $ / shares | 6 Months Ended | ||
Jun. 30, 2015 | Dec. 31, 2014 | ||
Weighted-average Fair Value per Unit at Grant Date | |||
Closing common share price | $ 46.13 | ||
Performance Shares | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Three-year risk-free rate | 1.10% | ||
Volatility rate, minimum | 12.00% | ||
Volatility rate, maximum | 18.00% | ||
Share Units | |||
Share Units, Nonvested as of January 1, 2014 | 1,162,377 | ||
Share Units, Granted | [1] | 567,240 | |
Share Units, Forfeitures | (1,944) | ||
Share Units, Vested | [2] | (85,694) | |
Share Units, Nonvested as of March 31, 2014 | 1,641,979 | ||
Weighted-average Fair Value per Unit at Grant Date | |||
Weighted-average Fair Value per Unit, Nonvested as of January 1, 2014 | $ 35.35 | ||
Weighted-average Fair Value per Unit, Grants | [1] | 52.88 | |
Weighted-average Fair Value per Unit, Forfeitures | 34.75 | ||
Weighted-average Fair Value per Unit, Vested | [2] | 46.79 | |
Weighted-average Fair Value per Unit, Nonvested as of March 31, 2014 | $ 40.81 | ||
Performance period | 3 years | ||
Risk free interest rate period | 3 years | ||
[1] | Performance share units granted to certain executive and nonexecutive officers and other eligible employees in 2015 under the 2014 Incentive Plan. | ||
[2] | (b)Performance share units vested due to the 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. |
Summary Of Significant Accoun39
Summary Of Significant Accounting Policies (Schedule Of Excise Taxes) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 51 | $ 50 | $ 108 | $ 110 |
Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | 41 | 39 | 75 | 73 |
Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 10 | $ 11 | $ 33 | $ 37 |
Summary Of Significant Accoun40
Summary Of Significant Accounting Policies Summary of Significant Accounting Policies (Schedule of Unrecognized Tax Benefits (Detriments)) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2015 | Dec. 31, 2014 | |
Schedule of Unrecognized Tax Benefits (Detriments) [Line Items] | ||
Unrecognized tax benefits (detriments) | $ 0 | $ 54 |
Union Electric Company | ||
Schedule of Unrecognized Tax Benefits (Detriments) [Line Items] | ||
Unrecognized tax benefits (detriments) | 0 | 0 |
Ameren Illinois Company | ||
Schedule of Unrecognized Tax Benefits (Detriments) [Line Items] | ||
Unrecognized tax benefits (detriments) | 0 | $ (1) |
2013 Tax Year | ||
Schedule of Unrecognized Tax Benefits (Detriments) [Line Items] | ||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | $ 53 |
Summary Of Significant Accoun41
Summary Of Significant Accounting Policies Summary of Significant Accounting Policies (Schedule of Unrecognized Tax Benefits (Detriments) That Would Impact the Effective Tax Rate) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Schedule of Unrecognized Tax Benefits (Detriments) That Would Impact Effective Tax Rate [Line Items] | ||
Unrecognized tax benefits (detriments) that would impact effective tax rate | $ 52 | |
Union Electric Company | ||
Schedule of Unrecognized Tax Benefits (Detriments) That Would Impact Effective Tax Rate [Line Items] | ||
Unrecognized tax benefits (detriments) that would impact effective tax rate | 0 | |
Ameren Illinois Company | ||
Schedule of Unrecognized Tax Benefits (Detriments) That Would Impact Effective Tax Rate [Line Items] | ||
Unrecognized tax benefits (detriments) that would impact effective tax rate | $ (1) |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative-Missouri) (Detail) - Subsequent Event Type [Domain] $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | 30 Months Ended |
Apr. 30, 2015USD ($) | Jun. 30, 2015USD ($) | Jun. 30, 2015mi | Dec. 31, 2012USD ($) | Jun. 30, 2015USD ($) | |
Union Electric Company | |||||
Rate And Regulatory Matters [Line Items] | |||||
Percentage of Customer's Sales Volume | 5.00% | ||||
Electric Distribution | Union Electric Company | MEEIA | |||||
Rate And Regulatory Matters [Line Items] | |||||
Energy Efficiency Program Spending | $ 197 | $ 147 | $ 95 | ||
Net Shared Benefits | 65 | 100 | $ 115 | ||
Incentive Award if Energy Efficiency Goals Are Achieved | $ 30 | $ 19 | |||
Achieved Percentage of Energy Efficiency Earnings For Incentive Award | 100.00% | 100.00% | 100.00% | 100.00% | |
Incentive Award if Energy Efficiency Goals Are Achieved, Period of Recognition | 2 years | ||||
Energy Efficiency Program Spending Period | 3 years | ||||
Net Shared Benefits, Recognition Period | 3 years | ||||
Incentive Award if Energy Efficiency Goals Are Achieved, Period | 3 years | ||||
Minimum Percentage of Energy Efficiency Goal Achievement For Company To Be Eligible For Incentive Award | 70.00% | ||||
Electric Distribution | Union Electric Company | Final Rate Order | |||||
Rate And Regulatory Matters [Line Items] | |||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 122 | ||||
Public Utilities, Approved Return on Equity, Percentage | 9.53% | ||||
Public Utilities, Approved Equity Capital Structure, Percentage | 51.80% | ||||
Rate Base | $ 7,000 | ||||
Illinois Rivers Project | Ameren Transmission Company of Illinois | |||||
Rate And Regulatory Matters [Line Items] | |||||
Transmission Line Miles | mi | 7 | ||||
Mark Twain Project | Ameren Transmission Company of Illinois | |||||
Rate And Regulatory Matters [Line Items] | |||||
Transmission Line Miles | mi | 100 | ||||
Electric Distribution - Net Energy Costs | Union Electric Company | Final Rate Order | |||||
Rate And Regulatory Matters [Line Items] | |||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 109 | ||||
Electric Distribution - Non-Energy Costs | Union Electric Company | Final Rate Order | |||||
Rate And Regulatory Matters [Line Items] | |||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 13 |
Rate And Regulatory Matters (43
Rate And Regulatory Matters (Narrative-Illinois) (Detail) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended |
Apr. 30, 2015USD ($) | Sep. 30, 2015USD ($) | Jun. 30, 2015USD ($)mi | Dec. 31, 2014USD ($) | |
Rate And Regulatory Matters [Line Items] | ||||
Regulatory assets | $ 1,560 | $ 1,582 | ||
Ameren Illinois Company | ||||
Rate And Regulatory Matters [Line Items] | ||||
Regulatory assets | 893 | $ 883 | ||
Ameren Illinois Company | Electric Distribution | Final Rate Order | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 15 | |||
Ameren Illinois Company | Gas Distribution | Pending Rate Case | Subsequent Event | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 45 | |||
Public Utilities, Requested Return on Equity, Percentage | 9.60% | |||
Public Utilities, Requested Equity Capital Structure, Percentage | 50.00% | |||
Rate Base | $ 1,200 | |||
Ameren Illinois Company | Gas Distribution | Final Rate Order | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Approved Return on Equity, Percentage | 9.10% | |||
Ameren Illinois Company | Gas Distribution | Rate order appeal | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Approved Return on Equity, Percentage | 10.40% | |||
Ameren Transmission Company of Illinois | Spoon River Project | ||||
Rate And Regulatory Matters [Line Items] | ||||
Transmission Line Miles | mi | 35 | |||
IEIMA | Ameren Illinois Company | Electric Distribution | 2015 IEMA Revenue Requirement Reconciliation | ||||
Rate And Regulatory Matters [Line Items] | ||||
Regulatory assets | $ 24 | |||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 110 | |||
IEIMA | Ameren Illinois Company | Electric Distribution | 2014 IEMA Revenue Requirement Reconciliation | ||||
Rate And Regulatory Matters [Line Items] | ||||
Regulatory assets | 102 | |||
IEIMA | Ameren Illinois Company | Electric Distribution | 2013 IEMA Revenue Requirement Reconciliation | ||||
Rate And Regulatory Matters [Line Items] | ||||
Regulatory assets | $ 36 | |||
Icc Staff Recommendation | IEIMA | Ameren Illinois Company | Electric Distribution | 2015 IEMA Revenue Requirement Reconciliation | Subsequent Event | ||||
Rate And Regulatory Matters [Line Items] | ||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 107 |
Rate And Regulatory Matters (44
Rate And Regulatory Matters (Narrative-Federal) (Detail) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||||
Feb. 28, 2015 | Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2012 | Jun. 30, 2015 | Jun. 30, 2014 | Dec. 31, 2014 | |
Rate And Regulatory Matters [Line Items] | |||||||
Current regulatory liabilities | $ 120 | $ 120 | $ 106 | ||||
Provision for Callaway construction and operating license | 69 | $ 0 | $ 0 | 69 | $ 0 | ||
New Nuclear Energy Center COL | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Provision for Callaway construction and operating license | 69 | ||||||
Ameren Illinois Company | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Current regulatory liabilities | 53 | 53 | 84 | ||||
Ameren Illinois Company | Final Rate Order | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Loss Contingency, Estimate of Possible Loss | 8 | 8 | |||||
Current regulatory liabilities | 6 | 6 | |||||
Payments for Legal Settlements | 2 | ||||||
Union Electric Company | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Current regulatory liabilities | 58 | 58 | $ 18 | ||||
Provision for Callaway construction and operating license | 69 | $ 0 | 69 | $ 0 | |||
Union Electric Company | New Nuclear Energy Center COL | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Investments in Power and Distribution Projects | $ 69 | 69 | |||||
Provision for Callaway construction and operating license | $ 69 | ||||||
Midwest Independent Transmission System Operator, Inc | Pending Ferc Case | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Customer Requested Rate on Equity | 8.67% | 9.15% | |||||
Public Utilities, Approved Return on Equity, Percentage | 12.38% | ||||||
Basis point reduction in FERC allowed base return on common equity | 0.50% | ||||||
Earnings reduction in FERC allowed base return on common equity | $ 4 | ||||||
Incentive adder to FERC allowed base return on common equity | 0.50% | ||||||
Midwest Independent Transmission System Operator, Inc | Pending Ferc Case | Ameren Illinois Company | |||||||
Rate And Regulatory Matters [Line Items] | |||||||
Earnings reduction in FERC allowed base return on common equity | $ 2 |
Short-Term Debt And Liquidity (
Short-Term Debt And Liquidity (Narrative) (Detail) - USD ($) | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Utilities | ||||
Line of Credit Facility [Line Items] | ||||
Short Term Debt, Weighted Average Interest Rate During Period | 0.08% | 0.19% | 0.08% | 0.29% |
Credit Agreements 2012 | ||||
Line of Credit Facility [Line Items] | ||||
Line of credit facility, maximum borrowing capacity | $ 1,200,000,000 | $ 1,200,000,000 | ||
Actual debt-to-capital ratio | 0.51 | 0.51 | ||
Line of Credit Facility, Covenant Terms, Default Provision, Maximum Indebtedness | $ 75,000,000 | $ 75,000,000 | ||
Credit Agreements 2012 | Maximum | ||||
Line of Credit Facility [Line Items] | ||||
Actual debt-to-capital ratio | 0.65 | 0.65 | ||
Interest Coverage Requirement | 200.00% | 200.00% | ||
Credit Agreements 2012 | Union Electric Company | Maximum | ||||
Line of Credit Facility [Line Items] | ||||
Actual debt-to-capital ratio | 0.65 | 0.65 | ||
Credit Agreements 2012 | Ameren Illinois Company | Maximum | ||||
Line of Credit Facility [Line Items] | ||||
Actual debt-to-capital ratio | 0.65 | 0.65 | ||
Missouri Credit Agreement 2012 | Union Electric Company | ||||
Line of Credit Facility [Line Items] | ||||
Actual debt-to-capital ratio | 0.50 | 0.50 | ||
Illinois Credit Agreement 2012 | Ameren Illinois Company | ||||
Line of Credit Facility [Line Items] | ||||
Actual debt-to-capital ratio | 0.46 | 0.46 |
Short-Term Debt And Liquidity46
Short-Term Debt And Liquidity Short-Term Debt and Liquidity (Commercial Paper outstanding) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Line of Credit Facility [Line Items] | ||
Commercial paper outstanding | $ 886 | $ 714 |
Ameren (parent) | ||
Line of Credit Facility [Line Items] | ||
Commercial paper outstanding | 836 | 585 |
Union Electric Company | ||
Line of Credit Facility [Line Items] | ||
Commercial paper outstanding | 38 | 97 |
Ameren Illinois Company | ||
Line of Credit Facility [Line Items] | ||
Commercial paper outstanding | $ 12 | $ 32 |
Short-Term Debt And Liquidity47
Short-Term Debt And Liquidity Short-Term Debt and Liquidity (Commercial Paper) (Details) - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 843 | $ 607 | |
Weighted Average Interest Rate | 0.56% | 0.32% | |
Peak Short Term Borrowings | [1] | $ 1,108 | $ 907 |
Peak Short Term Borrowings Interest Rate | 0.70% | 0.70% | |
Ameren (parent) | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 754 | $ 328 | |
Weighted Average Interest Rate | 0.57% | 0.32% | |
Peak Short Term Borrowings | [1] | $ 849 | $ 503 |
Peak Short Term Borrowings Interest Rate | 0.70% | 0.35% | |
Union Electric Company | |||
Line of Credit Facility [Line Items] | |||
Average Daily Commercial Paper Borrowings Outstanding | $ 84 | $ 146 | |
Weighted Average Interest Rate | 0.50% | 0.31% | |
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 | $ 5 | $ 242 | |
Weighted Average Interest Rate | 0.44% | 0.32% | |
Peak Short Term Borrowings | [1] | $ 39 | $ 300 |
Peak Short Term Borrowings Interest Rate | 0.60% | 0.34% | |
[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 Fin48
Long-Term Debt And Equity Financings (Narrative) (Detail) - USD ($) | 1 Months Ended | 6 Months Ended | |
Apr. 30, 2015 | Jun. 30, 2015 | Jun. 30, 2014 | |
Long-Term Debt And Equity Financings [Line Items] | |||
Redemptions of Long-term Debt | $ 114,000,000 | $ 692,000,000 | |
Union Electric Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Capital contribution from parent | 224,000,000 | 0 | |
Redemptions of Long-term Debt | $ 114,000,000 | 104,000,000 | |
Ameren Missouri And Ameren Illinois | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Assumed interest rate | 5.00% | ||
Dividend rate | 6.00% | ||
Ameren Illinois Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Redemptions of Long-term Debt | $ 0 | $ 163,000,000 | |
Ameren Illinois Company | Federal Energy Regulatory Commission Restriction | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Common stock equity to total capitalization | 53.00% | ||
Ameren Illinois Company | Minimum | Federal Energy Regulatory Commission Restriction | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Common stock equity to total capitalization | 30.00% | ||
Secured Debt | Senior Secured Notes, 3.65%, Due 2045 | Union Electric Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Debt Instrument, Face Amount | $ 250,000,000 | ||
Debt Instrument, Interest Rate, Stated Percentage | 3.65% | ||
Proceeds from Issuance of Secured Debt | $ 247,000,000 | ||
Secured Debt | Senior Secured Notes 4.75% Due 2015 | Union Electric Company | |||
Long-Term Debt And Equity Financings [Line Items] | |||
Redemptions of Long-term Debt | $ 114,000,000 | ||
Debt Instrument, Interest Rate, Stated Percentage | 4.75% |
Long-Term Debt And Equity Fin49
Long-Term Debt And Equity Financings (Schedule Of Covered Ratio) (Detail) - Jun. 30, 2015 $ in Millions | USD ($) | |
Union Electric Company | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Bonds Issuable | [1] | $ 3,305 |
Preferred Stock Issuable | 2,095 | |
Retired bond capacity | $ 946 | |
Union Electric Company | Actual Ratio [Member] | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Restricted payment interest coverage ratio, Actual | 3.5 | |
Dividend Coverage Ratio | 94.4 | |
Ameren Illinois Company | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Bonds Issuable | [1],[2] | $ 3,533 |
Preferred Stock Issuable | [3] | 203 |
Retired bond capacity | $ 204 | |
Ameren Illinois Company | Actual Ratio [Member] | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Restricted payment interest coverage ratio, Actual | 6.7 | |
Dividend Coverage Ratio | 2.8 | |
Minimum | Union Electric Company | Minimum Required Ratio [Member] | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Restricted payment interest coverage ratio, Actual | [4] | 2 |
Dividend Coverage Ratio | [5] | 2.5 |
Minimum | Ameren Illinois Company | Minimum Required Ratio [Member] | ||
Long-Term Debt And Equity Financings [Line Items] | ||
Restricted payment interest coverage ratio, Actual | [4] | 2 |
Dividend Coverage Ratio | [5] | 1.5 |
[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 $204 million at Ameren Missouri and Ameren Illinois, respectively. | |
[2] | Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. The amount of bonds issuable by Ameren Illinois is also subject to the lien restrictions contained in the 2012 Illinois Credit Agreement. | |
[3] | Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinoisā articles of incorporation. | |
[4] | Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. | |
[5] | Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective companyās articles of incorporation. |
Other Income and Expenses (Deta
Other Income and Expenses (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | [1] | $ 6 | $ 9 | $ 11 | $ 16 |
Interest income on industrial development revenue bonds | [1] | 6 | 7 | 13 | 14 |
Interest and dividend income | [1] | 4 | 2 | 8 | 5 |
Other | [1] | 0 | 3 | 3 | 4 |
Total miscellaneous income | [1] | 16 | 21 | 35 | 39 |
Donations | [1] | 2 | 1 | 10 | 6 |
Other | [1] | 4 | 3 | 7 | 7 |
Total miscellaneous expense | [1] | 6 | 4 | 17 | 13 |
Union Electric Company | |||||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | 5 | 8 | 9 | 15 | |
Interest income on industrial development revenue bonds | 6 | 7 | 13 | 14 | |
Interest and dividend income | 1 | 1 | 1 | 1 | |
Total miscellaneous income | 12 | 16 | 23 | 30 | |
Donations | 1 | 1 | 3 | 3 | |
Other | 1 | 1 | 2 | 3 | |
Total miscellaneous expense | 2 | 2 | 5 | 6 | |
Ameren Illinois Company | |||||
Other Nonoperating Income (Expense) [Line Items] | |||||
Allowance for equity funds used during construction | 1 | 1 | 2 | 1 | |
Interest and dividend income | 3 | 1 | 7 | 3 | |
Other | 0 | 3 | 2 | 4 | |
Total miscellaneous income | 4 | 5 | 11 | 8 | |
Donations | 1 | 4 | 3 | ||
Other | 1 | 1 | 3 | 2 | |
Total miscellaneous expense | $ 2 | $ 1 | $ 7 | $ 5 | |
[1] | Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. |
Derivative Financial Instrume51
Derivative Financial Instruments (Open Gross Derivative Volumes By Commodity Type) (Detail) lb in Thousands, gal in Millions, MWh in Millions, MMBTU in Millions | Jun. 30, 2015galMWhMMBTUlb | Dec. 31, 2014galMWhMMBTUlb | |
Fuel Oils | |||
Derivative [Line Items] | |||
Quantity | gal | [1] | 39 | 50 |
Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 156 | 136 | |
Power | |||
Derivative [Line Items] | |||
Quantity | 11 | 12 | |
Uranium | |||
Derivative [Line Items] | |||
Quantity | lb | 316 | 332 | |
Union Electric Company | Fuel Oils | |||
Derivative [Line Items] | |||
Quantity | gal | [1] | 39 | 50 |
Union Electric Company | Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 29 | 28 | |
Union Electric Company | Power | |||
Derivative [Line Items] | |||
Quantity | 1 | 1 | |
Union Electric Company | Uranium | |||
Derivative [Line Items] | |||
Quantity | lb | 316 | 332 | |
Ameren Illinois Company | Natural Gas | |||
Derivative [Line Items] | |||
Quantity | MMBTU | 127 | 108 | |
Ameren Illinois Company | Power | |||
Derivative [Line Items] | |||
Quantity | 10 | 11 | |
[1] | Fuel oils consist of heating oil and ultra-low-sulfur diesel. |
Derivative Financial Instrume52
Derivative Financial Instruments (Derivative Instruments Carrying Value) (Detail) - Not Designated As Hedging Instrument - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Derivative [Line Items] | ||
Derivative assets | $ 31 | $ 19 |
Derivative liabilities | 237 | 232 |
Fuel Oils | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 2 |
Fuel Oils | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 14 | 22 |
Fuel Oils | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 5 | 7 |
Natural Gas | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 2 | |
Natural Gas | Other Assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | |
Natural Gas | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 28 | 37 |
Natural Gas | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 21 | 19 |
Power | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 29 | 15 |
Power | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 13 | 14 |
Power | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 154 | 131 |
Uranium | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 2 | 2 |
Union Electric Company | ||
Derivative [Line Items] | ||
Derivative assets | 30 | 18 |
Derivative liabilities | 34 | 46 |
Union Electric Company | Fuel Oils | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 2 |
Union Electric Company | Fuel Oils | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 14 | 22 |
Union Electric Company | Fuel Oils | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 5 | 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 | 0 | |
Union Electric Company | Natural Gas | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 4 | 6 |
Union Electric Company | Natural Gas | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 7 | 6 |
Union Electric Company | Power | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 29 | 15 |
Union Electric Company | Power | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 2 | 3 |
Union Electric Company | Power | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 0 | 0 |
Union Electric Company | Uranium | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 2 | 2 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 1 |
Derivative liabilities | 203 | 186 |
Ameren Illinois Company | Fuel Oils | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Fuel Oils | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 0 | 0 |
Ameren Illinois Company | Fuel Oils | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 0 | 0 |
Ameren Illinois Company | Natural Gas | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | |
Ameren Illinois Company | Natural Gas | Other Assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | |
Ameren Illinois Company | Natural Gas | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 0 | 0 |
Ameren Illinois Company | Natural Gas | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 14 | 13 |
Ameren Illinois Company | Natural Gas | Mark To Market Derivative Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 24 | 31 |
Ameren Illinois Company | Power | Other Current Assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Power | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 0 | 0 |
Ameren Illinois Company | Power | Other Deferred Credits And Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 154 | 131 |
Ameren Illinois Company | Power | Mark To Market Derivative Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | 11 | 11 |
Ameren Illinois Company | Uranium | Other Current Liabilities | ||
Derivative [Line Items] | ||
Derivative liabilities | $ 0 | $ 0 |
Derivative Financial Instrume53
Derivative Financial Instruments (Cumulative Amount Of Pretax Net Gains (Losses) On All Derivative Instruments In OCI) (Detail) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 | |
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | $ 120 | $ 106 | |
Current losses deferred as regulatory assets | 223 | 295 | |
Fuel Oils | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 1 | ||
Current losses deferred as regulatory assets | 14 | ||
Fuel Oils | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (19) | [1] | (29) |
Natural Gas | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 28 | ||
Natural Gas | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (48) | [2] | (54) |
Power | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 29 | ||
Current losses deferred as regulatory assets | 13 | ||
Power | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (138) | [3] | (130) |
Uranium | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 2 | ||
Uranium | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (2) | [4] | (2) |
Union Electric Company | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 58 | 18 | |
Current losses deferred as regulatory assets | 133 | 163 | |
Union Electric Company | Fuel Oils | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 1 | ||
Current losses deferred as regulatory assets | 14 | ||
Union Electric Company | Fuel Oils | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (19) | [1] | (29) |
Union Electric Company | Natural Gas | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 4 | ||
Union Electric Company | Natural Gas | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (11) | [2] | (11) |
Union Electric Company | Power | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 29 | ||
Current losses deferred as regulatory assets | 2 | ||
Union Electric Company | Power | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | 27 | [3] | 12 |
Union Electric Company | Uranium | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 2 | ||
Union Electric Company | Uranium | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (2) | [4] | (2) |
Ameren Illinois Company | |||
Derivative [Line Items] | |||
Current gains deferred as regulatory liabilities | 53 | 84 | |
Current losses deferred as regulatory assets | 89 | 129 | |
Ameren Illinois Company | Fuel Oils | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | 0 | [1] | 0 |
Ameren Illinois Company | Natural Gas | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 24 | ||
Ameren Illinois Company | Natural Gas | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (37) | [2] | (43) |
Ameren Illinois Company | Power | |||
Derivative [Line Items] | |||
Current losses deferred as regulatory assets | 11 | ||
Ameren Illinois Company | Power | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | (165) | [3] | (142) |
Ameren Illinois Company | Uranium | Regulatory Liabilities Or Assets [Member] | |||
Derivative [Line Items] | |||
Cumulative deferred pretax gains (losses) | $ 0 | [4] | $ 0 |
[1] | Represents net losses associated with fuel oils derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās rail transportation surcharges for coal through December 2017. Current gains deferred as regulatory liabilities include $1 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $14 million at Ameren and Ameren Missouri. | ||
[2] | Represents net losses associated with natural gas derivative contracts. These contracts are a partial hedge of natural gas requirements through March 2021 at Ameren and Ameren Missouri and through October 2018 at Ameren Illinois. Current losses deferred as regulatory assets include $28 million, $4 million, and $24 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. | ||
[3] | Represents net gains (losses) associated with power derivative contracts. These contracts are a partial hedge of power price requirements through May 2032 at Ameren and Ameren Illinois and through December 2016 at Ameren Missouri. Current gains deferred as regulatory liabilities include $29 million at Ameren and Ameren Missouri. Current losses deferred as regulatory assets include $13 million, $2 million, and $11 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively. | ||
[4] | Represents net losses on uranium derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouriās uranium requirements through January 2017. Current losses deferred as regulatory assets include $2 million at Ameren and Ameren Missouri. |
Derivative Financial Instrume54
Derivative Financial Instruments (Offsetting Derivative Assets and Liabilities) (Details) - Commodity Contract - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 | |||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | $ 31 | [1] | $ 19 | [2] | |
Derivative Instruments | 3 | 5 | |||
Derivative, Collateral, Obligation to Return Cash | [3] | 0 | 0 | ||
Net Amount | 28 | 14 | |||
Gross Amounts Recognized in the Balance Sheet | 237 | [1] | 232 | [2] | |
Derivative Instruments | 3 | 5 | |||
Cash Collateral Received/Posted | [3] | 2 | 5 | ||
Net Amount | 232 | 222 | |||
Union Electric Company | |||||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | 30 | [1] | 18 | [2] | |
Derivative Instruments | 3 | 5 | |||
Derivative, Collateral, Obligation to Return Cash | [3] | 0 | 0 | ||
Net Amount | 27 | 13 | |||
Gross Amounts Recognized in the Balance Sheet | 34 | [1] | 46 | [2] | |
Derivative Instruments | 3 | 5 | |||
Cash Collateral Received/Posted | [3] | 2 | 5 | ||
Net Amount | 29 | 36 | |||
Ameren Illinois Company | |||||
Offsetting Assets and Liabilities [Line Items] | |||||
Gross Amounts Recognized in the Balance Sheet | 1 | 1 | |||
Derivative Instruments | 0 | 0 | |||
Derivative, Collateral, Obligation to Return Cash | [3] | 0 | 0 | ||
Net Amount | 1 | 1 | |||
Gross Amounts Recognized in the Balance Sheet | 203 | [1] | 186 | [2] | |
Derivative Instruments | 0 | 0 | |||
Cash Collateral Received/Posted | [3] | 0 | 0 | ||
Net Amount | $ 203 | $ 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 āOther current liabilitiesā and āOther deferred credits and liabilitiesā on the balance sheet. Cash collateral posted reduces gross liability balances and is included in āOther current assetsā and āOther assetsā on the balance sheet. |
Derivative Financial Instrume55
Derivative Financial Instruments (Maximum Exposure If Counterparties Fail To Perform On Contracts) (Detail) $ in Millions | 6 Months Ended |
Jun. 30, 2015USD ($) | |
Derivative [Line Items] | |
Maximum exposure to counterparties related to derivative contracts | $ 11 |
Union Electric Company | |
Derivative [Line Items] | |
Maximum exposure to counterparties related to derivative contracts | 11 |
Ameren Illinois Company | |
Derivative [Line Items] | |
Maximum exposure to counterparties related to derivative contracts | $ 0 |
Derivative Financial Instrume56
Derivative Financial Instruments (Potential Loss On Counterparty Exposures) (Detail) $ in Millions | Jun. 30, 2015USD ($) |
Concentration Risk [Line Items] | |
Potential loss on counterparty exposures related to derivative contracts | $ 11 |
Ameren Illinois Company | |
Concentration Risk [Line Items] | |
Potential loss on counterparty exposures related to derivative contracts | 0 |
Union Electric Company | |
Concentration Risk [Line Items] | |
Potential loss on counterparty exposures related to derivative contracts | $ 11 |
Derivative Financial Instrume57
Derivative Financial Instruments (Derivative Instruments With Credit Risk-Related Contingent Features) (Detail) $ in Millions | Jun. 30, 2015USD ($) | |
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | [1] | $ 157 |
Cash Collateral Posted | 3 | |
Potential Aggregate Amount of Additional Collateral Required | [2] | 145 |
Union Electric Company | ||
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | [1] | 80 |
Cash Collateral Posted | 3 | |
Potential Aggregate Amount of Additional Collateral Required | [2] | 73 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Aggregate Fair Value of Derivative Liabilities | [1] | 77 |
Cash Collateral Posted | 0 | |
Potential Aggregate Amount of Additional Collateral Required | [2] | $ 72 |
[1] | Prior to 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) (Detail) $ in Millions | 6 Months Ended | 12 Months Ended | |||
Jun. 30, 2015USD ($)$ / credit$ / MMBTU$ / lb$ / MWh$ / MW | Dec. 31, 2014USD ($)$ / MMBTU$ / credit$ / MW$ / MWh$ / lb | ||||
Natural Gas | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.21% | [1],[2] | 0.43% | [3],[4] | |
Nodal basis | (0.60) | [5] | (0.40) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 2.01% | [1],[2] | 13.00% | [3],[4] | |
Nodal basis | 0 | [5] | 0.10 | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.83% | [1],[2] | 3.00% | [3],[4] | |
Nodal basis | (0.40) | [5] | (0.20) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Option Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 31.00% | |||
Nodal basis | $ / MWh | [6] | (0.40) | |||
Natural Gas | Option Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 144.00% | |||
Nodal basis | $ / MWh | [6] | 0 | |||
Natural Gas | Option Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 63.00% | |||
Nodal basis | $ / MWh | [6] | (0.20) | |||
Natural Gas | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 0 | [7] | $ 1 | [8] | |
Natural Gas | Union Electric Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 0.57% | |||
Nodal basis | $ / MWh | [6] | (0.10) | |||
Credit risk | [3],[4] | 0.43% | |||
Natural Gas | Union Electric Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 13.00% | |||
Nodal basis | $ / MWh | [6] | (0.10) | |||
Credit risk | [3],[4] | 0.43% | |||
Natural Gas | Union Electric Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | [3],[4] | 5.00% | |||
Nodal basis | $ / MWh | [6] | (0.10) | |||
Credit risk | [3],[4] | 0.43% | |||
Natural Gas | Union Electric Company | Option Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 31.00% | |||
Nodal basis | $ / MWh | [6] | (0.40) | |||
Natural Gas | Union Electric Company | Option Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 144.00% | |||
Nodal basis | $ / MWh | [6] | 0 | |||
Natural Gas | Union Electric Company | Option Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 53.00% | |||
Nodal basis | $ / MWh | [6] | (0.30) | |||
Natural Gas | Union Electric Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | [8] | $ 0 | |||
Natural Gas | Ameren Illinois Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.21% | [1],[2] | 0.43% | [3],[4] | |
Nodal basis | (0.6) | [5] | (0.40) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Ameren Illinois Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 2.01% | [1],[2] | 2.00% | [3],[4] | |
Nodal basis | 0 | [5] | 0.10 | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Ameren Illinois Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.83% | [1],[2] | 0.83% | [3],[4] | |
Nodal basis | (0.4) | [5] | (0.20) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Natural Gas | Ameren Illinois Company | Option Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 50.00% | |||
Nodal basis | $ / MWh | [6] | (0.10) | |||
Natural Gas | Ameren Illinois Company | Option Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 144.00% | |||
Nodal basis | $ / MWh | [6] | 0 | |||
Natural Gas | Ameren Illinois Company | Option Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | [3] | 94.00% | |||
Nodal basis | $ / MWh | [6] | (0.10) | |||
Natural Gas | Ameren Illinois Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 0 | [7] | $ 1 | [8] | |
Natural Gas | Derivative Liabilities | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | (1) | [7] | (2) | [8] | |
Natural Gas | Derivative Liabilities | Union Electric Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | [8] | (1) | |||
Natural Gas | Derivative Liabilities | Ameren Illinois Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ (1) | [7] | $ (1) | [8] | |
Fuel Oils | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Option Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 32.00% | [1] | 3.00% | [3] | |
Fuel Oils | Option Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 50.00% | [1] | 39.00% | [3] | |
Fuel Oils | Option Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 37.00% | [1] | 32.00% | [3] | |
Fuel Oils | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 1 | [7] | $ 2 | [8] | |
Fuel Oils | Union Electric Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Union Electric Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Union Electric Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | [6],[9] | 5.00% | |||
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Fuel Oils | Union Electric Company | Option Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 32.00% | [1] | 3.00% | [3] | |
Fuel Oils | Union Electric Company | Option Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 50.00% | [1] | 39.00% | [3] | |
Fuel Oils | Union Electric Company | Option Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Volatilities | 37.00% | [1] | 32.00% | [3] | |
Fuel Oils | Union Electric Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 1 | [7] | $ 2 | [8] | |
Fuel Oils | Derivative Liabilities | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | (2) | [7] | (8) | [8] | |
Fuel Oils | Derivative Liabilities | Union Electric Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ (2) | [7] | $ (8) | [8] | |
Power | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.39% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | (11) | [5] | (6) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | 26 | [10] | 27 | [11] | |
Estimated auction price | (1,006) | [5] | (1,833) | [6] | |
Power | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 13.86% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | (1) | [5] | 0 | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | 45 | [10] | 50 | [11] | |
Estimated auction price | 1,606 | [5] | 2,743 | [6] | |
Power | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 8.64% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | (3) | [5] | (2) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | 31 | [10] | 32 | [11] | |
Estimated auction price | 184 | [5] | 171 | [6] | |
Power | Fundamental Energy Production Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 0.00% | [6],[13] | |
Estimated future gas prices | 3 | [5] | 4 | [6] | |
Power | Fundamental Energy Production Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 1.00% | [6],[13] | |
Estimated future gas prices | 6 | [5] | 5 | [6] | |
Power | Fundamental Energy Production Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 1.00% | [6],[13] | |
Estimated future gas prices | 4 | [5] | 4 | [6] | |
Power | Contract Price Allocation | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 5 | [5] | 5 | [6] | |
Power | Contract Price Allocation | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 7 | [5] | 7 | [6] | |
Power | Contract Price Allocation | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 6 | [5] | 6 | [6] | |
Power | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 29 | [7],[14] | $ 11 | [8],[15] | |
Power | Union Electric Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 0.39% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | $ / MWh | [1] | (11) | |||
Credit risk | [3],[4] | 0.43% | |||
Average forward peak and off-peak pricing | 26 | [1] | 27 | [3] | |
Estimated auction price | (1,006) | [5] | (1,833) | [6] | |
Power | Union Electric Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 13.86% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | $ / MWh | [1] | (4) | |||
Credit risk | [3],[4] | 0.43% | |||
Average forward peak and off-peak pricing | 45 | [1] | 50 | [3] | |
Estimated auction price | 1,606 | [5] | 2,743 | [6] | |
Power | Union Electric Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Counterparty credit risk | 8.64% | [1],[2] | 0.26% | [3],[4] | |
Nodal basis | $ / MWh | [1] | (9) | |||
Credit risk | [3],[4] | 0.43% | |||
Average forward peak and off-peak pricing | 34 | [1] | 32 | [3] | |
Estimated auction price | 184 | [5] | 171 | [6] | |
Power | Union Electric Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 29 | [7],[14] | $ 11 | [8],[15] | |
Power | Ameren Illinois Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Nodal basis | (6) | [5] | (6) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | $ / MWh | [5] | 27 | |||
Average forward pricing | $ / lb | [6] | 27 | |||
Power | Ameren Illinois Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Nodal basis | (1) | [5] | 0 | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | $ / MWh | [5] | 37 | |||
Average forward pricing | $ / lb | [6] | 38 | |||
Power | Ameren Illinois Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Nodal basis | (3) | [5] | (2) | [6] | |
Credit risk | 0.40% | [1],[2] | 0.43% | [3],[4] | |
Average forward peak and off-peak pricing | $ / MWh | [5] | 30 | |||
Average forward pricing | $ / lb | [6] | 32 | |||
Power | Ameren Illinois Company | Fundamental Energy Production Model | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 0.00% | [6],[13] | |
Estimated future gas prices | 3 | [5] | 4 | [6] | |
Power | Ameren Illinois Company | Fundamental Energy Production Model | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 1.00% | [6],[13] | |
Estimated future gas prices | 6 | [5] | 5 | [6] | |
Power | Ameren Illinois Company | Fundamental Energy Production Model | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Escalation rate | 2.00% | [5],[12] | 1.00% | [6],[13] | |
Estimated future gas prices | 4 | [5] | 4 | [6] | |
Power | Ameren Illinois Company | Contract Price Allocation | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 5 | [5] | 5 | [6] | |
Power | Ameren Illinois Company | Contract Price Allocation | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 7 | [5] | 7 | [6] | |
Power | Ameren Illinois Company | Contract Price Allocation | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Estimated renewable energy credit costs | $ / credit | 6 | [5] | 6 | [6] | |
Power | Ameren Illinois Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 0 | [7],[14] | $ 0 | [8],[15] | |
Power | Derivative Liabilities | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | (167) | [7],[14] | (144) | [8],[15] | |
Power | Derivative Liabilities | Union Electric Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | (2) | [7],[14] | (2) | [8],[15] | |
Power | Derivative Liabilities | Ameren Illinois Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ (165) | [7],[14] | $ (142) | [8],[15] | |
Uranium | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 36 | [5] | 35 | [6] | |
Uranium | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 39 | [5] | 40 | [6] | |
Uranium | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 37 | [5] | 36 | [6] | |
Uranium | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 0 | [7] | $ 0 | [8] | |
Uranium | Union Electric Company | Discounted Cash Flow | Minimum | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 36 | [5] | 35 | [6] | |
Uranium | Union Electric Company | Discounted Cash Flow | Maximum | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 39 | [5] | 40 | [6] | |
Uranium | Union Electric Company | Discounted Cash Flow | Weighted Average | |||||
Fair Value Inputs [Abstract] | |||||
Average forward pricing | 37 | [5] | 36 | [6] | |
Uranium | Union Electric Company | Derivative Assets | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative assets | $ 0 | [7] | $ 0 | [8] | |
Uranium | Derivative Liabilities | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | (2) | [7] | (2) | [8] | |
Uranium | Derivative Liabilities | Union Electric Company | |||||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | |||||
Derivative liabilities | $ (2) | [7] | $ (2) | [8] | |
[1] | (b)Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. | ||||
[2] | (c)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. | ||||
[3] | (b)Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. | ||||
[4] | (c)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. | ||||
[5] | (e)Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. | ||||
[6] | (e)Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. | ||||
[7] | (a)The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[8] | (a)The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[9] | (f)Escalation rate applies to fuel oil prices 2017 and beyond. | ||||
[10] | (g)The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. | ||||
[11] | (h)The balance at Ameren is comprised of Ameren Missouri and Ameren Illinois power contracts, which respond differently to unobservable input changes due to their opposing positions. As such, refer to the power sensitivity analysis for each company above. | ||||
[12] | (h)Escalation rate applies to power prices 2026 and beyond. | ||||
[13] | (i)Escalation rate applies to power prices 2026 and beyond. | ||||
[14] | (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. | ||||
[15] | (g)Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2018. Valuations beyond 2018 use fundamentally modeled pricing by month for peak and off-peak demand. |
Fair Value Measurements (Narrat
Fair Value Measurements (Narrative) (Detail) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Valuation adjustments related to net derivative contracts, liabilities | $ 1 | $ 1 |
Union Electric Company | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Valuation adjustments related to net derivative contracts, liabilities | 1 | 1 |
Ameren Illinois Company | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Valuation adjustments related to net derivative contracts, liabilities | $ 1 | $ 1 |
Fair Value Measurements (Sche60
Fair Value Measurements (Schedule Of Fair Value Hierarchy Of Assets And Liabilities Measured At Fair Value On Recurring Basis) (Detail) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | $ 557 | [1] | $ 547 | [2] | |
Assets fair value | 588 | [3] | 566 | [4] | |
Excluded receivables, payables, and accrued income, net | (2) | 2 | |||
Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 557 | [1] | 547 | [2] | |
Assets fair value | 587 | [3] | 565 | [4] | |
Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 31 | [3] | 19 | [4] | |
Derivative liabilities | 237 | [3] | 232 | [4] | |
Commodity Contract | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 30 | [3] | 18 | [4] | |
Derivative liabilities | 34 | [3] | 46 | [4] | |
Commodity Contract | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | 1 | |||
Derivative liabilities | 203 | [3] | 186 | [4] | |
Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 2 | [4] | |
Derivative liabilities | 19 | [3] | 29 | [4] | |
Commodity Contract | Fuel Oils | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 2 | [4] | |
Derivative liabilities | 19 | [3] | 29 | [4] | |
Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 2 | [4] | |
Derivative liabilities | 49 | [3] | 56 | [4] | |
Commodity Contract | Natural Gas | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 1 | |||
Derivative liabilities | 11 | [3] | 12 | [4] | |
Commodity Contract | Natural Gas | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 1 | [4] | |
Derivative liabilities | 38 | [3] | 44 | [4] | |
Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 29 | [3] | 15 | [4] | |
Derivative liabilities | 167 | [3] | 145 | [4] | |
Commodity Contract | Power | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 29 | [3] | 15 | [4] | |
Derivative liabilities | 2 | [3] | 3 | [4] | |
Commodity Contract | Power | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 165 | [3] | 142 | [4] | |
Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 2 | [3] | 2 | [4] | |
Commodity Contract | Uranium | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 2 | [3] | 2 | [4] | |
Cash and cash equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 6 | 1 | |||
Cash and cash equivalents | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 6 | 1 | |||
Equity Securities | U.S. large capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 370 | 364 | |||
Equity Securities | U.S. large capitalization | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 370 | 364 | |||
Debt Securities | Corporate bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 59 | 63 | |||
Debt Securities | Corporate bonds | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 59 | 63 | |||
Debt Securities | US treasury and government securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 100 | 102 | |||
Debt Securities | US treasury and government securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 100 | 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 | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
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 | 376 | 365 | |||
Assets fair value | 376 | [3] | 365 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 376 | 365 | |||
Assets fair value | 376 | [3] | 365 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 17 | [3] | 22 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 17 | [3] | 22 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | ||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 17 | [3] | 21 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Fuel Oils | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 17 | [3] | 21 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 1 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Natural Gas | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 0 | |||
Derivative liabilities | 0 | [3] | 1 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Natural Gas | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Power | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Power | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Commodity Contract | Uranium | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | [4] | |
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Cash and cash equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 6 | 1 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Cash and cash equivalents | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 6 | 1 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Equity Securities | U.S. large capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 370 | 364 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Equity Securities | U.S. large capitalization | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 370 | 364 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | Corporate bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | Corporate bonds | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | US treasury and government securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | US treasury and government securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | Other Debt Securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Quoted Prices In Active Markets For Identical Assets or Liabilities (Level 1) | Debt Securities | Other Debt Securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 181 | 182 | |||
Assets fair value | 182 | [3] | 187 | [4] | |
Significant Other Observable Inputs (Level 2) | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 181 | 182 | |||
Assets fair value | 181 | [3] | 187 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 5 | [4] | |
Derivative liabilities | 48 | [3] | 54 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 5 | [4] | |
Derivative liabilities | 11 | [3] | 11 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 37 | [3] | 43 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 0 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Fuel Oils | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 0 | [4] | |
Derivative liabilities | 0 | [3] | 0 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 1 | [4] | |
Derivative liabilities | 48 | [3] | 53 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Natural Gas | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 1 | |||
Derivative liabilities | 11 | [3] | 10 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Natural Gas | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 0 | [4] | |
Derivative liabilities | 37 | [3] | 43 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 4 | [4] | |
Derivative liabilities | 0 | [3] | 1 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Power | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 4 | [4] | |
Derivative liabilities | 0 | [3] | 1 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Power | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | ||
Significant Other Observable Inputs (Level 2) | Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | [4] | |
Significant Other Observable Inputs (Level 2) | Commodity Contract | Uranium | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 0 | [3] | 0 | [4] | |
Significant Other Observable Inputs (Level 2) | Cash and cash equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Observable Inputs (Level 2) | Cash and cash equivalents | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Observable Inputs (Level 2) | Equity Securities | U.S. large capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Observable Inputs (Level 2) | Equity Securities | U.S. large capitalization | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | Corporate bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 59 | 63 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | Corporate bonds | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 59 | 63 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | US treasury and government securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 100 | 102 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | US treasury and government securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 100 | 102 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | Other Debt Securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Significant Other Observable Inputs (Level 2) | Debt Securities | Other Debt Securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 22 | 17 | |||
Significant Other Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Assets fair value | 30 | [3] | 14 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Assets fair value | 30 | [3] | 13 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 30 | [3] | 14 | [4] | |
Derivative liabilities | 172 | [3] | 156 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 30 | [3] | 13 | [4] | |
Derivative liabilities | 6 | [3] | 13 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 166 | [3] | 143 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Fuel Oils | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 2 | [4] | |
Derivative liabilities | 2 | [3] | 8 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Fuel Oils | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 1 | [3] | 2 | [4] | |
Derivative liabilities | 2 | [3] | 8 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Natural Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 1 | [4] | |
Derivative liabilities | 1 | [3] | 2 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Natural Gas | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | [4] | 0 | |||
Derivative liabilities | 0 | [3] | 1 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Natural Gas | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 0 | [3] | 1 | [4] | |
Derivative liabilities | 1 | [3] | 1 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Power | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 29 | [3] | 11 | [4] | |
Derivative liabilities | 167 | [3] | 144 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Power | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative assets | 29 | [3] | 11 | [4] | |
Derivative liabilities | 2 | [3] | 2 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Power | Ameren Illinois Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 165 | [3] | 142 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Uranium | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 2 | [3] | 2 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Commodity Contract | Uranium | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Derivative liabilities | 2 | [3] | 2 | [4] | |
Significant Other Unobservable Inputs (Level 3) | Cash and cash equivalents | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Cash and cash equivalents | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Equity Securities | U.S. large capitalization | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Equity Securities | U.S. large capitalization | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | Corporate bonds | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | Corporate bonds | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | US treasury and government securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | US treasury and government securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | Other Debt Securities | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | 0 | 0 | |||
Significant Other Unobservable Inputs (Level 3) | Debt Securities | Other Debt Securities | Union Electric Company | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Nuclear Decommissioning Trust Fund | $ 0 | $ 0 | |||
[1] | Balance excludes $(2) million of receivables, payables, and accrued income, net. | ||||
[2] | Balance excludes $2 million of receivables, payables, and accrued income, net. | ||||
[3] | The derivative asset and liability balances are presented net of counterparty credit considerations. | ||||
[4] | The derivative asset and liability balances are presented net of counterparty credit considerations. |
Fair Value Measurements (Sche61
Fair Value Measurements (Schedule Of Changes In The Fair Value Of Financial Assets And Liabilities Classified As Level Three In The Fair Value Hierarchy) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Fuel Oils | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | $ (6) | $ 1 | $ (6) | $ 5 |
Included in regulatory assets/liabilities | 1 | 1 | (1) | |
Settlements | 2 | 3 | (2) | |
Transfer out of Level 3 | 2 | 0 | 2 | 0 |
Ending balance | (1) | 2 | (1) | 2 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 3 | 1 | 0 | 0 |
Uranium | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (1) | (5) | (2) | (6) |
Included in regulatory assets/liabilities | (1) | (4) | (4) | |
Settlements | 2 | 3 | ||
Ending balance | (2) | (7) | (2) | (7) |
Change in unrealized gains (losses) related to assets/liabilities held at period end | (1) | (4) | 0 | (4) |
Natural Gas | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | 0 | 0 | (1) | 0 |
Purchases | (1) | 1 | (1) | |
Settlements | 0 | (1) | 0 | 1 |
Ending balance | (1) | 0 | (1) | 0 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 0 | 0 | 0 | 0 |
Power | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (160) | (110) | (133) | (89) |
Included in regulatory assets/liabilities | (4) | 3 | (31) | (14) |
Purchases | 29 | 34 | 29 | 34 |
Settlements | (3) | (14) | (3) | (19) |
Transfer out of Level 3 | 0 | (1) | ||
Ending balance | (138) | (88) | (138) | (88) |
Change in unrealized gains (losses) related to assets/liabilities held at period end | (4) | 14 | (29) | (2) |
Union Electric Company | Fuel Oils | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (6) | 1 | (6) | 5 |
Included in regulatory assets/liabilities | 1 | 1 | (1) | |
Settlements | 2 | 3 | (2) | |
Transfer out of Level 3 | 2 | 0 | 2 | 0 |
Ending balance | (1) | 2 | (1) | 2 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 3 | 1 | 0 | 0 |
Union Electric Company | Uranium | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (1) | (5) | (2) | (6) |
Included in regulatory assets/liabilities | (1) | (4) | (4) | |
Settlements | 2 | 3 | ||
Ending balance | (2) | (7) | (2) | (7) |
Change in unrealized gains (losses) related to assets/liabilities held at period end | (1) | (4) | 0 | (4) |
Union Electric Company | Natural Gas | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (1) | 0 | (1) | 0 |
Purchases | 0 | 0 | 0 | |
Settlements | 1 | 0 | 1 | 0 |
Ending balance | 0 | 0 | 0 | 0 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 0 | 0 | 0 | 0 |
Union Electric Company | Power | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | 4 | 10 | 9 | 19 |
Included in regulatory assets/liabilities | 0 | (13) | (2) | (18) |
Purchases | 29 | 34 | 29 | 34 |
Settlements | (6) | (15) | (9) | (20) |
Transfer out of Level 3 | 0 | (1) | ||
Ending balance | 27 | 15 | 27 | 15 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 1 | (1) | 0 | (3) |
Ameren Illinois Company | Fuel Oils | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Transfer out of Level 3 | 0 | 0 | 0 | 0 |
Ameren Illinois Company | Natural Gas | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | 1 | 0 | 0 | 0 |
Purchases | (1) | 1 | (1) | |
Settlements | (1) | (1) | (1) | 1 |
Ending balance | (1) | 0 | (1) | 0 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 0 | 0 | 0 | 0 |
Ameren Illinois Company | Power | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (164) | (120) | (142) | (108) |
Included in regulatory assets/liabilities | (4) | 16 | (29) | 4 |
Purchases | 0 | 0 | 0 | 0 |
Settlements | 3 | 1 | 6 | 1 |
Transfer out of Level 3 | 0 | 0 | ||
Ending balance | (165) | (103) | (165) | (103) |
Change in unrealized gains (losses) related to assets/liabilities held at period end | $ (5) | $ 15 | $ (29) | $ 1 |
Fair Value Measurements (Sche62
Fair Value Measurements (Schedule Of Transfers Between Fair Value Hierarchy Levels) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Fuel Oils | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | $ 2 | $ 0 | $ 2 | $ 0 |
Power | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | 0 | (1) | ||
Union Electric Company | Fuel Oils | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | 2 | 0 | 2 | 0 |
Union Electric Company | Power | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | 0 | (1) | ||
Ameren Illinois Company | Fuel Oils | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | 0 | 0 | $ 0 | $ 0 |
Ameren Illinois Company | Power | ||||
Derivative [Line Items] | ||||
Assets Transfers out of Level 3 | $ 0 | $ 0 |
Fair Value Measurements (Sche63
Fair Value Measurements (Schedule Of Carrying Amounts And Estimated Fair Values Of Long-Term Debt And Preferred Stock) (Detail) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 | |
Fair Value | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | [1] | $ 6,919 | $ 7,135 |
Preferred stock | [1] | 122 | 122 |
Fair Value | Union Electric Company | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | 4,492 | 4,518 | |
Preferred stock | 73 | 73 | |
Fair Value | Ameren Illinois Company | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | 2,427 | 2,517 | |
Preferred stock | 49 | 49 | |
Carrying Amount | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | [1] | 6,376 | 6,240 |
Preferred stock | [1] | 142 | 142 |
Carrying Amount | Union Electric Company | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | 4,135 | 3,999 | |
Preferred stock | 80 | 80 | |
Carrying Amount | Ameren Illinois Company | |||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||
Long-term debt (including current portion) | 2,241 | 2,241 | |
Preferred stock | $ 62 | $ 62 | |
[1] | Preferred stock is recorded in āNoncontrolling Interestsā on the consolidated balance sheet. |
Related Party Transactions (Sch
Related Party Transactions (Schedule of Related Party Transactions) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||||
Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | $ 12 | $ 8 | $ 19 | $ 13 | |||
Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | 1 | 1 | 2 | 1 | |||
Purchased Power | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Expenses | 4 | 3 | 6 | 4 | |||
Ameren Missouri Power Supply Agreements with Ameren Illinois | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | 4 | 3 | 5 | 3 | |||
Ameren Missouri and Ameren Illinois Rent and Facility Services | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | 7 | 4 | 13 | 9 | |||
Ameren Missouri and Ameren Illinois Rent and Facility Services | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | 1 | 1 | 2 | 1 | |||
Ameren Missouri and Ameren Illinois miscellaneous support services [Member] | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | 1 | 1 | 1 | 1 | |||
Ameren Missouri and Ameren Illinois miscellaneous support services [Member] | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Revenues | [1] | 1 | 1 | 1 | 1 | ||
Ameren Illinois Power Supply Agreements with Ameren Missouri | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Expenses | 4 | 3 | 5 | 3 | |||
Ameren Illinois Transmission Agreements with ATXI | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Expenses | 1 | [1] | 1 | [1] | 1 | 1 | |
Ameren Services Support Services Agreement | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Expenses | 32 | 32 | 66 | 65 | |||
Ameren Services Support Services Agreement | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Operating Expenses | 30 | 27 | 59 | 54 | |||
Related Party Money Pool Interest | Union Electric Company | |||||||
Related Party Transaction [Line Items] | |||||||
Interest Charges | [1] | 1 | 1 | 1 | 1 | ||
Related Party Money Pool Interest | Ameren Illinois Company | |||||||
Related Party Transaction [Line Items] | |||||||
Interest Charges | [1] | $ 1 | $ 1 | $ 1 | $ 1 | ||
[1] | Amount less than $1 million. |
Related Party Transactions Narr
Related Party Transactions Narrative (Details) - 6 months ended Jun. 30, 2015 - Ameren Illinois Company - Ameren Illinois Power Supply Agreements with Ameren Missouri | MWh$ / MWh |
Related Party Transaction [Line Items] | |
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power | 667,000 |
Long-term Contract for Purchase of Electric Power, Related Party Contract, Fixed Power, Rate | $ / MWh | 36 |
Commitments And Contingencies66
Commitments And Contingencies (Callaway Energy Center) (Detail) - Jun. 30, 2015 - USD ($) | Total | |
Commitments And Contingencies [Line Items] | ||
Threshold for which a retrospective assessment for a covered loss is necessary | $ 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 | 128,000,000 | |
Maximum annual payment in calendar year per reactor incident under Price Andersen Liability Provisions of Atomic Energy Act | 19,000,000 | |
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 | |
Inflationary adjustment prescribed by most recent Price-Anderson Act renewal, in years | 5 years | |
Aggregate nuclear power industry insurance policy limit for losses from terrorist attacks within twelve month period | $ 3,240,000,000 | |
Public Liability | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | [1] | 13,361,000,000 |
Maximum Assessments for Single Incidents | 128,000,000 | |
Public Liability And Nuclear Worker Liability - American Nuclear Insurers | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | 375,000,000 | |
Maximum Assessments for Single Incidents | 0 | |
Public Liability And Nuclear Worker Liability - Pool Participation | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | [2] | 12,986,000,000 |
Maximum Assessments for Single Incidents | [3] | 128,000,000 |
Property Damage | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | 3,250,000,000 | |
Maximum Assessments for Single Incidents | 27,000,000 | |
Property Damage - Nuclear Electric Insurance Ltd | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | [4] | 2,750,000,000 |
Maximum Assessments for Single Incidents | [5] | 27,000,000 |
Property Damage European Mutual Association for Nuclear Insurance | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | [6] | 500,000,000 |
Replacement Power - Nuclear Electric Insurance Ltd | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | [7] | 490,000,000 |
Maximum Assessments for Single Incidents | [5] | 10,000,000 |
Amount of weekly indemnity coverage thereafter not exceeding policy limit | 490,000,000 | |
Sub-limit of for non-nuclear events | 328,000,000 | |
Non-radiation event | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | 2,250,000,000 | |
Aggregate nuclear power industry insurance policy limit for losses from terrorist attacks within twelve month period | 1,830,000,000 | |
Radiation Event | ||
Commitments And Contingencies [Line Items] | ||
Maximum Coverages | $ 500,000,000 | |
[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 $128 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] | 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. | |
[7] | Provides replacement power cost insurance in the event of a prolonged accidental outage. Weekly indemnity 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. |
Commitments And Contingencies67
Commitments And Contingencies (Other Obligations) (Detail) - Jun. 30, 2015 $ in Millions | USD ($)MWh |
Long-term Purchase Commitment [Line Items] | |
Total Other Obligations | $ 5,110 |
Union Electric Company | |
Long-term Purchase Commitment [Line Items] | |
Total Other Obligations | 3,247 |
Ameren Illinois Company | |
Long-term Purchase Commitment [Line Items] | |
Total Other Obligations | $ 1,822 |
Amount of Megawatthours | MWh | 5,526,000 |
Long-term Purchase Commitment, Amount | $ 185 |
Commitments And Contingencies68
Commitments And Contingencies (Environmental Matters) (Detail) - Jun. 30, 2015 $ in Millions | USD ($)site |
Minimum | |
Loss Contingencies [Line Items] | |
Estimated capital costs to comply with existing and known federal and state air emissions regulations | $ 350 |
Maximum | |
Loss Contingencies [Line Items] | |
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 400 |
Former Coal Tar Distillery | Union Electric Company | |
Loss Contingencies [Line Items] | |
Range of possible loss, minimum | 2 |
Range of possible loss maximum | 5 |
Accrual for environmental loss contingencies | 2 |
Former Coal Ash Landfill | Ameren Illinois Company | |
Loss Contingencies [Line Items] | |
Range of possible loss, minimum | 0.5 |
Range of possible loss maximum | 6 |
Accrual for environmental loss contingencies | 0.5 |
Manufactured Gas Plant | |
Loss Contingencies [Line Items] | |
Accrual for environmental loss contingencies | $ 245 |
Manufactured Gas Plant | Ameren Illinois Company | |
Loss Contingencies [Line Items] | |
Number of remediation sites | site | 44 |
Range of possible loss, minimum | $ 240 |
Range of possible loss maximum | 309 |
Accrual for environmental loss contingencies | 240 |
Other Environmental | Ameren Illinois Company | |
Loss Contingencies [Line Items] | |
Accrual for environmental loss contingencies | 0.7 |
Sauget Area Two | Union Electric Company | |
Loss Contingencies [Line Items] | |
Range of possible loss, minimum | 1 |
Range of possible loss maximum | 2.5 |
Accrual for environmental loss contingencies | 1 |
Substation in St Charles, Missouri | Union Electric Company | |
Loss Contingencies [Line Items] | |
Accrual for environmental loss contingencies | $ 1 |
Commitments And Contingencies69
Commitments And Contingencies (Pumped-Storage Hydroelectric Facility Breach) (Detail) - Union Electric Company $ in Millions | Jun. 30, 2015USD ($) |
Loss Contingencies [Line Items] | |
Insurance settlements receivable | $ 41 |
Insurance Claim | $ 53 |
Commitments And Contingencies70
Commitments And Contingencies (Asbestos-Related Litigation) (Detail) - Jun. 30, 2015 - Asbestos-Related $ in Millions | USD ($)defendantlawsuit | |
Loss Contingencies [Line Items] | ||
Average number of total defendants named | defendant | 73 | |
Asbestos-related lawsuits were pending | [1] | 49 |
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] | ||
Asbestos-related lawsuits were pending | 28 | |
Range of possible loss, minimum | $ | $ 3 | |
Ameren Illinois Company | ||
Loss Contingencies [Line Items] | ||
Asbestos-related lawsuits were pending | 36 | |
Range of possible loss, minimum | $ | $ 5 | |
Ameren Corporation | ||
Loss Contingencies [Line Items] | ||
Asbestos-related lawsuits were pending | 1 | |
[1] | Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. |
Callaway Energy Center (Narrati
Callaway Energy Center (Narrative) (Detail) - 6 months ended Jun. 30, 2015 - Nuclear Plant $ in Millions | USD ($)mill |
Nuclear Waste Matters [Line Items] | |
Number of mills charged for NWF fee | 1 |
Annual decommissioning costs included in costs of service | $ | $ 7 |
Retirement Benefits (Narrative)
Retirement Benefits (Narrative) (Detail) $ in Millions | Jun. 30, 2015USD ($) |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Defined benefit plan, estimated future employer contributions in each of the next five years | $ 290 |
Minimum | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Defined benefit plan, estimated future employer contributions in each of the next five years | 25 |
Maximum | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Defined benefit plan, estimated future employer contributions in each of the next five years | $ 115 |
Retirement Benefits (Components
Retirement Benefits (Components Of Net Periodic Benefit Cost) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
Pension Plan | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Service cost | $ 22 | $ 19 | $ 46 | $ 40 | |
Interest cost | 43 | 42 | 87 | 91 | |
Expected return on plan assets | (62) | (57) | (124) | (114) | |
Prior service cost (benefit) | 0 | 0 | |||
Actuarial loss | 19 | 12 | 37 | 24 | |
Settlement loss | 1 | 0 | 1 | 0 | |
Net periodic benefit cost | [1] | 23 | 16 | 47 | 41 |
Other Postretirement Benefit Plan, Defined Benefit | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Service cost | 6 | 4 | 11 | 9 | |
Interest cost | 12 | 12 | 24 | 25 | |
Expected return on plan assets | (17) | (16) | (34) | (32) | |
Prior service cost (benefit) | (1) | (1) | (2) | (2) | |
Actuarial loss | 2 | (2) | 3 | (3) | |
Net periodic benefit cost | [1] | $ 2 | $ (3) | $ 2 | $ (3) |
[1] | Includes amounts for Ameren registrants and nonregistrant subsidiaries. |
Retirement Benefits (Summary Of
Retirement Benefits (Summary Of Benefit Plan Costs Incurred) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
Pension Plan | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | [1] | $ 23 | $ 16 | $ 47 | $ 41 |
Pension Plan | Union Electric Company | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | 13 | 8 | 28 | 25 | |
Pension Plan | Ameren Illinois Company | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | 10 | 7 | 19 | 15 | |
Pension Plan | Other Affiliated Entities and Intercompany Eliminations [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | 1 | 1 | |||
Other Postretirement Benefit Plan, Defined Benefit | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | [1] | 2 | (3) | 2 | (3) |
Other Postretirement Benefit Plan, Defined Benefit | Union Electric Company | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | 3 | 1 | 4 | 2 | |
Other Postretirement Benefit Plan, Defined Benefit | Ameren Illinois Company | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | $ (1) | (3) | $ (2) | (4) | |
Other Postretirement Benefit Plan, Defined Benefit | Other Affiliated Entities and Intercompany Eliminations [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Net periodic benefit cost | $ (1) | $ (1) | |||
[1] | Includes amounts for Ameren registrants and nonregistrant subsidiaries. |
Divestiture Transactions and 75
Divestiture Transactions and Discontinued Operations Divestiture Transactions and Discontinued Operations (Narrative) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | |||
Jan. 31, 2014 | Dec. 31, 2013 | Jun. 30, 2015 | Dec. 31, 2014 | Mar. 14, 2013 | |
New Ameren Energy Resources Company, LLC | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Range of possible loss maximum | $ 25 | ||||
Notes, Loans and Financing Receivable, Net, Current | 9 | $ 12 | |||
Collateral to be posted if credit ratings are below investment grade | 19 | ||||
Buyer's indemnification guarantee obligation | $ 25 | ||||
Loss contingency accrual | 25 | ||||
Guarantees Outstanding | 79 | ||||
Letters of Credit Outstanding, Amount | 9 | ||||
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 | |||
Proceeds from Asset Sale Held in Escrow | $ 17 | ||||
Ameren Energy Marketing Company | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Guarantees, Maximum Exposure | $ 6 |
Divestiture Transactions and 76
Divestiture Transactions and Discontinued Operations Divestiture Transactions and Discontinued Operations (Components of Discontinued Operations in Consolidated Statement of Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Discontinued Operations and Disposal Groups [Abstract] | ||||
Operating revenues | $ 0 | $ 0 | $ 0 | $ 1 |
Operating benefits (expenses) | 0 | (1) | 3 | (3) |
Operating income (loss) before income tax | 0 | (1) | 3 | (2) |
Income tax benefit | 52 | 0 | 49 | 0 |
Income (loss) from discontinued operations, net of taxes | $ 52 | $ (1) | $ 52 | $ (2) |
Divestiture Transactions and 77
Divestiture Transactions and Discontinued Operations Divestiture Transactions and Discontinued Operations (Components of Assets and Liabilities on Consolidated Balance Sheet) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Assets of discontinued operations | ||
Accumulated deferred income taxes, net | $ 15 | $ 15 |
Total assets of discontinued operations | 15 | 15 |
Liabilities of discontinued operations | ||
Accounts payable and other current obligations | 2 | 1 |
Asset retirement obligations | 30 | 32 |
Total liabilities of discontinued operations | $ 32 | $ 33 |
Segment Information (Schedule O
Segment Information (Schedule Of Segment Reporting Information By Segment) (Detail) $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2015USD ($) | Jun. 30, 2014USD ($) | Jun. 30, 2015USD ($) | Jun. 30, 2014USD ($) | Dec. 31, 2014USD ($) | ||
Segment Reporting Information [Line Items] | ||||||
Number of Reportable Segments | 2 | |||||
External revenues | $ 1,401 | $ 1,419 | $ 2,957 | $ 3,013 | ||
Net income (loss) attributable to Ameren Corporation from continuing operations | 98 | 150 | 206 | 247 | ||
Total assets | 23,152 | 23,152 | $ 22,676 | |||
Assets of discontinued operations (Note 12) | 15 | $ 15 | 15 | |||
Union Electric Company | ||||||
Segment Reporting Information [Line Items] | ||||||
Number of Reportable Segments | 1 | |||||
External revenues | 872 | 893 | $ 1,665 | 1,704 | ||
Intersegment revenues | 12 | 7 | 19 | 13 | ||
Net income (loss) attributable to Ameren Corporation from continuing operations | 61 | 126 | 102 | 173 | ||
Total assets | 13,721 | $ 13,721 | 13,541 | |||
Ameren Illinois Company | ||||||
Segment Reporting Information [Line Items] | ||||||
Number of Reportable Segments | 1 | |||||
External revenues | 512 | 518 | $ 1,256 | 1,292 | ||
Intersegment revenues | 1 | 1 | 2 | 1 | ||
Net income (loss) attributable to Ameren Corporation from continuing operations | 31 | 28 | 84 | 81 | ||
Total assets | 8,500 | 8,500 | 8,381 | |||
Other | ||||||
Segment Reporting Information [Line Items] | ||||||
External revenues | 17 | 8 | 36 | 17 | ||
Intersegment revenues | 1 | 1 | ||||
Net income (loss) attributable to Ameren Corporation from continuing operations | 6 | (4) | 20 | (7) | ||
Total assets | 1,036 | 1,036 | 942 | |||
Intersegment Eliminations | ||||||
Segment Reporting Information [Line Items] | ||||||
Intersegment revenues | (13) | (8) | (22) | (15) | ||
Total assets | (120) | (120) | (203) | |||
Consolidated, Continuing Operations | ||||||
Segment Reporting Information [Line Items] | ||||||
External revenues | 1,401 | 1,419 | 2,957 | 3,013 | ||
Net income (loss) attributable to Ameren Corporation from continuing operations | 98 | $ 150 | 206 | $ 247 | ||
Total assets | [1] | $ 23,137 | $ 23,137 | $ 22,661 | ||
[1] | Excludes total assets from discontinued operations of $15 million as of JuneĀ 30, 2015, and December 31, 2014. |