Cover Page
Cover Page - shares | 9 Months Ended | |
Sep. 30, 2022 | Oct. 31, 2022 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Sep. 30, 2022 | |
Document Transition Report | false | |
Entity File Number | 1-14756 | |
Entity Registrant Name | Ameren Corporation | |
Entity Tax Identification Number | 43-1723446 | |
Entity Incorporation, State or Country Code | MO | |
Entity Address, Address Line One | 1901 Chouteau Avenue | |
Entity Address, City or Town | St. Louis | |
Entity Address, State or Province | MO | |
Entity Address, Postal Zip Code | 63103 | |
City Area Code | (314) | |
Local Phone Number | 621-3222 | |
Title of 12(b) Security | Common Stock, $0.01 par value per share | |
Trading Symbol(s) | AEE | |
Security Exchange Name | NYSE | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Emerging growth company | false | |
Entity Shell Company | false | |
Shares outstanding | 258,522,169 | |
Entity Central Index Key | 0001002910 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | Q3 | |
Amendment Flag | false | |
Union Electric Company | ||
Entity Information [Line Items] | ||
Entity File Number | 1-2967 | |
Entity Registrant Name | Union Electric Company | |
Entity Tax Identification Number | 43-0559760 | |
Entity Incorporation, State or Country Code | MO | |
Entity Address, Address Line One | 1901 Chouteau Avenue | |
Entity Address, City or Town | St. Louis | |
Entity Address, State or Province | MO | |
Entity Address, Postal Zip Code | 63103 | |
City Area Code | (314) | |
Local Phone Number | 621-3222 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Non-accelerated Filer | |
Entity Small Business | false | |
Emerging growth company | false | |
Entity Shell Company | false | |
Shares outstanding | 102,123,834 | |
Entity Central Index Key | 0000100826 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | Q3 | |
Amendment Flag | false | |
Ameren Illinois Company | ||
Entity Information [Line Items] | ||
Entity File Number | 1-3672 | |
Entity Registrant Name | Ameren Illinois Company | |
Entity Tax Identification Number | 37-0211380 | |
Entity Incorporation, State or Country Code | IL | |
Entity Address, Address Line One | 10 Richard Mark Way | |
Entity Address, City or Town | Collinsville | |
Entity Address, State or Province | IL | |
Entity Address, Postal Zip Code | 62234 | |
City Area Code | (618) | |
Local Phone Number | 343-8150 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Non-accelerated Filer | |
Entity Small Business | false | |
Emerging growth company | false | |
Entity Shell Company | false | |
Shares outstanding | 25,452,373 | |
Entity Central Index Key | 0000018654 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | Q3 | |
Amendment Flag | false | |
Ameren Illinois Company | Former Address | ||
Entity Information [Line Items] | ||
Entity Address, Address Line One | 10 Executive Drive | |
Entity Address, City or Town | Collinsville | |
Entity Address, State or Province | IL | |
Entity Address, Postal Zip Code | 62234 |
Consolidated Statement of Incom
Consolidated Statement of Income (Loss) and Comprehensive Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Operating Revenues: | ||||
Total operating revenues | $ 2,306 | $ 1,811 | $ 5,911 | $ 4,849 |
Operating Expenses: | ||||
Fuel | 117 | 184 | 376 | 422 |
Purchased power | 563 | 159 | 1,058 | 479 |
Natural gas purchased for resale | 58 | 45 | 431 | 275 |
Other operations and maintenance | 475 | 457 | 1,427 | 1,289 |
Depreciation and amortization | 350 | 290 | 965 | 856 |
Taxes other than income taxes | 144 | 142 | 415 | 392 |
Total operating expenses | 1,707 | 1,277 | 4,672 | 3,713 |
Operating Income | 599 | 534 | 1,239 | 1,136 |
Other Income, Net | 58 | 56 | 180 | 151 |
Interest Charges | 126 | 94 | 356 | 290 |
Income Before Income Taxes | 531 | 496 | 1,063 | 997 |
Income Taxes | 78 | 70 | 148 | 128 |
Net Income | 453 | 426 | 915 | 869 |
Less: Net Income Attributable to Noncontrolling Interests | 1 | 1 | 4 | 4 |
Net Income Attributable to Ameren Common Shareholders | 452 | 425 | 911 | 865 |
Pension and other postretirement benefit plan activity, net of income taxes (benefit) | 0 | 1 | 1 | 1 |
Comprehensive Income | 453 | 427 | 916 | 870 |
Less: Comprehensive Income Attributable to Noncontrolling Interests | 1 | 1 | 4 | 4 |
Comprehensive Income Attributable to Ameren Common Shareholders | $ 452 | $ 426 | $ 912 | $ 866 |
Earnings Per Share, Basic and Diluted [Abstract] | ||||
Earnings per Common Share – Basic | $ 1.75 | $ 1.66 | $ 3.53 | $ 3.38 |
Earnings per Common Share – Diluted | $ 1.74 | $ 1.65 | $ 3.51 | $ 3.36 |
Weighted-average Common Shares Outstanding – Basic | 258.4 | 257.3 | 258.2 | 255.9 |
Weighted-average Common Shares Outstanding – Diluted | 259.5 | 258.6 | 259.3 | 257.2 |
Electric | ||||
Operating Revenues: | ||||
Total operating revenues | $ 2,140 | $ 1,668 | $ 4,971 | $ 4,108 |
Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 166 | 143 | 940 | 741 |
Union Electric Company | ||||
Operating Revenues: | ||||
Total operating revenues | 1,359 | 1,129 | 3,096 | 2,642 |
Operating Expenses: | ||||
Fuel | 117 | 184 | 376 | 422 |
Purchased power | 247 | 57 | 458 | 195 |
Natural gas purchased for resale | 7 | 4 | 65 | 40 |
Other operations and maintenance | 252 | 240 | 744 | 683 |
Depreciation and amortization | 208 | 161 | 550 | 474 |
Taxes other than income taxes | 106 | 104 | 281 | 266 |
Total operating expenses | 937 | 750 | 2,474 | 2,080 |
Operating Income | 422 | 379 | 622 | 562 |
Other Income, Net | 25 | 27 | 72 | 74 |
Interest Charges | 58 | 32 | 157 | 107 |
Income Before Income Taxes | 389 | 374 | 537 | 529 |
Income Taxes | (9) | (2) | (13) | (7) |
Net Income | 398 | 376 | 550 | 536 |
Preferred Stock Dividends | 1 | 1 | 3 | 3 |
Net Income Attributable to Parent | 397 | 375 | 547 | 533 |
Union Electric Company | Electric | ||||
Operating Revenues: | ||||
Total operating revenues | 1,338 | 1,113 | 2,966 | 2,543 |
Union Electric Company | Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 21 | 16 | 130 | 99 |
Ameren Illinois Company | ||||
Operating Revenues: | ||||
Total operating revenues | 904 | 645 | 2,697 | 2,097 |
Operating Expenses: | ||||
Purchased power | 319 | 108 | 608 | 298 |
Natural gas purchased for resale | 51 | 41 | 366 | 235 |
Other operations and maintenance | 215 | 217 | 663 | 604 |
Depreciation and amortization | 130 | 118 | 382 | 350 |
Taxes other than income taxes | 34 | 34 | 122 | 114 |
Total operating expenses | 749 | 518 | 2,141 | 1,601 |
Operating Income | 155 | 127 | 556 | 496 |
Other Income, Net | 26 | 19 | 75 | 49 |
Interest Charges | 42 | 41 | 125 | 123 |
Income Before Income Taxes | 139 | 105 | 506 | 422 |
Income Taxes | 36 | 26 | 130 | 107 |
Net Income | 103 | 79 | 376 | 315 |
Preferred Stock Dividends | 0 | 0 | 1 | 1 |
Net Income Attributable to Parent | 103 | 79 | 375 | 314 |
Ameren Illinois Company | Electric | ||||
Operating Revenues: | ||||
Total operating revenues | 758 | 518 | 1,886 | 1,455 |
Ameren Illinois Company | Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | $ 146 | $ 127 | $ 811 | $ 642 |
Consolidated Statement of Inc_2
Consolidated Statement of Income (Loss) and Comprehensive Income (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Income Statement [Abstract] | ||||
Pension and other postretirement benefit plan activity, tax | $ 0 | $ 0 | $ 0 | $ 0 |
Consolidated Balance Sheet
Consolidated Balance Sheet - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Current Assets: | ||
Cash and cash equivalents | $ 7 | $ 8 |
Accounts receivable - trade (less allowance for doubtful accounts) | 665 | 434 |
Unbilled revenue | 366 | 301 |
Miscellaneous accounts receivable | 62 | 85 |
Inventories | 695 | 592 |
Current regulatory assets | 346 | 319 |
Current collateral assets | 145 | 66 |
Other current assets | 232 | 163 |
Total current assets | 2,518 | 1,968 |
Property, Plant, and Equipment, Net | 30,608 | 29,261 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 910 | 1,159 |
Goodwill | 411 | 411 |
Regulatory assets | 1,405 | 1,289 |
Pension and other postretirement benefits | 813 | 756 |
Other assets | 992 | 891 |
Total investments and other assets | 4,531 | 4,506 |
TOTAL ASSETS | 37,657 | 35,735 |
Current Liabilities: | ||
Current maturities of long-term debt | 155 | 505 |
Short-term debt | 1,221 | 545 |
Accounts and wages payable | 820 | 1,095 |
Taxes accrued | 216 | 74 |
Current regulatory liabilities | 179 | 113 |
Other current liabilities | 584 | 494 |
Total current liabilities | 3,175 | 2,826 |
Long-term Debt, Net | 13,577 | 12,562 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 3,785 | 3,499 |
Regulatory liabilities | 5,658 | 5,848 |
Asset retirement obligations | 771 | 757 |
Other deferred credits and liabilities | 361 | 414 |
Total deferred credits and other liabilities | 10,575 | 10,518 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 3 | 3 |
Other paid-in capital, principally premium on common stock | 6,548 | 6,502 |
Retained earnings | 3,636 | 3,182 |
Accumulated other comprehensive income | 14 | 13 |
Total shareholders’ equity | 10,201 | 9,700 |
Noncontrolling Interests | 129 | 129 |
Total equity | 10,330 | 9,829 |
TOTAL LIABILITIES AND EQUITY | 37,657 | 35,735 |
Union Electric Company | ||
Current Assets: | ||
Cash and cash equivalents | 0 | 0 |
Accounts receivable - trade (less allowance for doubtful accounts) | 302 | 190 |
Accounts receivable – affiliates | 23 | 44 |
Unbilled revenue | 204 | 142 |
Miscellaneous accounts receivable | 39 | 71 |
Inventories | 438 | 419 |
Current regulatory assets | 243 | 127 |
Current collateral assets | 140 | 66 |
Other current assets | 99 | 76 |
Total current assets | 1,488 | 1,135 |
Property, Plant, and Equipment, Net | 15,829 | 15,296 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 910 | 1,159 |
Regulatory assets | 642 | 523 |
Pension and other postretirement benefits | 223 | 208 |
Other assets | 425 | 401 |
Total investments and other assets | 2,200 | 2,291 |
TOTAL ASSETS | 19,517 | 18,722 |
Current Liabilities: | ||
Current maturities of long-term debt | 55 | 55 |
Short-term debt | 178 | 165 |
Accounts and wages payable | 339 | 631 |
Accounts payable – affiliates | 43 | 46 |
Taxes accrued | 183 | 34 |
Interest accrued | 69 | 60 |
Mark-to-market derivative liabilities | 113 | 53 |
Current regulatory liabilities | 87 | 57 |
Other current liabilities | 114 | 116 |
Total current liabilities | 1,181 | 1,217 |
Long-term Debt, Net | 6,085 | 5,564 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 1,952 | 1,852 |
Regulatory liabilities | 3,004 | 3,354 |
Asset retirement obligations | 767 | 753 |
Other deferred credits and liabilities | 70 | 71 |
Total deferred credits and other liabilities | 5,793 | 6,030 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 511 | 511 |
Other paid-in capital, principally premium on common stock | 2,725 | 2,725 |
Preferred stock | 80 | 80 |
Retained earnings | 3,142 | 2,595 |
Total shareholders’ equity | 6,458 | 5,911 |
TOTAL LIABILITIES AND EQUITY | 19,517 | 18,722 |
Ameren Illinois Company | ||
Current Assets: | ||
Cash and cash equivalents | 0 | 0 |
Accounts receivable - trade (less allowance for doubtful accounts) | 349 | 228 |
Accounts receivable – affiliates | 9 | 24 |
Unbilled revenue | 162 | 159 |
Miscellaneous accounts receivable | 14 | 1 |
Inventories | 257 | 173 |
Mark-to-market derivative assets | 68 | 28 |
Current regulatory assets | 100 | 180 |
Other current assets | 39 | 30 |
Total current assets | 998 | 823 |
Property, Plant, and Equipment, Net | 13,011 | 12,223 |
Investments and Other Assets: | ||
Goodwill | 411 | 411 |
Regulatory assets | 742 | 752 |
Pension and other postretirement benefits | 456 | 427 |
Other assets | 514 | 399 |
Total investments and other assets | 2,123 | 1,989 |
TOTAL ASSETS | 16,132 | 15,035 |
Current Liabilities: | ||
Current maturities of long-term debt | 100 | 400 |
Short-term debt | 353 | 103 |
Accounts and wages payable | 394 | 361 |
Accounts payable – affiliates | 117 | 64 |
Current regulatory liabilities | 92 | 54 |
Other current liabilities | 275 | 251 |
Total current liabilities | 1,331 | 1,233 |
Long-term Debt, Net | 4,389 | 3,992 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 1,670 | 1,558 |
Regulatory liabilities | 2,532 | 2,374 |
Other deferred credits and liabilities | 195 | 238 |
Total deferred credits and other liabilities | 4,397 | 4,170 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 0 | 0 |
Other paid-in capital, principally premium on common stock | 2,914 | 2,914 |
Preferred stock | 49 | 49 |
Retained earnings | 3,052 | 2,677 |
Total shareholders’ equity | 6,015 | 5,640 |
TOTAL LIABILITIES AND EQUITY | $ 16,132 | $ 15,035 |
Consolidated Balance Sheet (Par
Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Accounts Receivable, Allowance for Credit Loss, Current | $ 31 | $ 29 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 400,000,000 | 400,000,000 |
Common Stock, Shares, Outstanding | 258,500,000 | 257,700,000 |
Union Electric Company | ||
Accounts Receivable, Allowance for Credit Loss, Current | $ 12 | $ 13 |
Common stock, par value (in dollars per share) | $ 5 | $ 5 |
Common stock, shares authorized (in shares) | 150,000,000 | 150,000,000 |
Common Stock, Shares, Outstanding | 102,100,000 | 102,100,000 |
Ameren Illinois Company | ||
Accounts Receivable, Allowance for Credit Loss, Current | $ 19 | $ 16 |
Common stock, no par value (in dollars per share) | $ 0 | $ 0 |
Common stock, shares authorized (in shares) | 45,000,000 | 45,000,000 |
Common Stock, Shares, Outstanding | 25,500,000 | 25,500,000 |
Consolidated Statement of Cash
Consolidated Statement of Cash Flows - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2022 | Sep. 30, 2021 | |
Cash Flows From Operating Activities: | ||
Net income | $ 915 | $ 869 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 1,016 | 903 |
Amortization of nuclear fuel | 46 | 37 |
Amortization of debt issuance costs and premium/discounts | 17 | 17 |
Deferred income taxes and investment tax credits, net | 137 | 139 |
Allowance for equity funds used during construction | (31) | (30) |
Stock-based compensation costs | 18 | 17 |
Other | 63 | 11 |
Changes in assets and liabilities: | ||
Receivables | (296) | (212) |
Inventories | (103) | (73) |
Accounts and wages payable | (128) | (143) |
Taxes accrued | 147 | 148 |
Regulatory assets and liabilities | (17) | (340) |
Assets, other | (87) | (58) |
Liabilities, other | 19 | (35) |
Pension and other postretirement benefits | (49) | (6) |
Counterparty collateral, net | (68) | (52) |
Net cash provided by operating activities | 1,599 | 1,192 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (2,437) | (2,613) |
Nuclear fuel expenditures | (22) | (19) |
Purchases of securities – nuclear decommissioning trust fund | (176) | (411) |
Sales and maturities of securities – nuclear decommissioning trust fund | 163 | 404 |
Other | 14 | (7) |
Net cash used in investing activities | (2,458) | (2,646) |
Cash Flows From Financing Activities: | ||
Dividends on common stock | (457) | (423) |
Dividends paid to noncontrolling interest holders | (4) | (4) |
Short-term debt, net | 675 | 63 |
Maturities of long-term debt | (450) | 0 |
Issuances of long-term debt | 1,118 | 1,423 |
Issuances of common stock | 29 | 297 |
Redemptions of Ameren Illinois preferred stock | 0 | (13) |
Employee payroll taxes related to stock-based compensation | (16) | (17) |
Debt issuance costs | (11) | (15) |
Other | 0 | (13) |
Net cash provided by financing activities | 884 | 1,298 |
Net change in cash, cash equivalents, and restricted cash | 25 | (156) |
Cash, cash equivalents, and restricted cash at beginning of year | 155 | 301 |
Cash, cash equivalents, and restricted cash at end of period | 180 | 145 |
Union Electric Company | ||
Cash Flows From Operating Activities: | ||
Net income | 550 | 536 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 603 | 522 |
Amortization of nuclear fuel | 46 | 37 |
Amortization of debt issuance costs and premium/discounts | 5 | 5 |
Deferred income taxes and investment tax credits, net | (17) | (7) |
Allowance for equity funds used during construction | (17) | (17) |
Other | 9 | 8 |
Changes in assets and liabilities: | ||
Receivables | (160) | (216) |
Inventories | (19) | (19) |
Accounts and wages payable | (192) | (145) |
Taxes accrued | 161 | 146 |
Regulatory assets and liabilities | (164) | (164) |
Assets, other | (9) | 20 |
Liabilities, other | 14 | (9) |
Pension and other postretirement benefits | (12) | 6 |
Counterparty collateral, net | (72) | (58) |
Net cash provided by operating activities | 726 | 645 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (1,237) | (1,567) |
Nuclear fuel expenditures | (22) | (19) |
Purchases of securities – nuclear decommissioning trust fund | (176) | (411) |
Sales and maturities of securities – nuclear decommissioning trust fund | 163 | 404 |
Money pool advances, net | 0 | 115 |
Other | 17 | 0 |
Net cash used in investing activities | (1,255) | (1,478) |
Cash Flows From Financing Activities: | ||
Dividends on preferred stock | (3) | (3) |
Short-term debt, net | 13 | 0 |
Issuances of long-term debt | 524 | 524 |
Capital contributions from parent | 0 | 183 |
Debt issuance costs | (6) | (5) |
Net cash provided by financing activities | 528 | 699 |
Net change in cash, cash equivalents, and restricted cash | (1) | (134) |
Cash, cash equivalents, and restricted cash at beginning of year | 8 | 145 |
Cash, cash equivalents, and restricted cash at end of period | 7 | 11 |
Ameren Illinois Company | ||
Cash Flows From Operating Activities: | ||
Net income | 376 | 315 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 381 | 349 |
Amortization of debt issuance costs and premium/discounts | 9 | 10 |
Deferred income taxes and investment tax credits, net | 92 | 134 |
Allowance for equity funds used during construction | (14) | (13) |
Other | 19 | 8 |
Changes in assets and liabilities: | ||
Receivables | (138) | 8 |
Inventories | (84) | (54) |
Accounts and wages payable | 62 | 12 |
Taxes accrued | 54 | (21) |
Regulatory assets and liabilities | 147 | (167) |
Assets, other | (75) | (59) |
Liabilities, other | 35 | 1 |
Pension and other postretirement benefits | (29) | (16) |
Net cash provided by operating activities | 835 | 507 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (1,145) | (1,026) |
Money pool advances, net | 0 | (41) |
Other | 0 | (7) |
Net cash used in investing activities | (1,145) | (1,074) |
Cash Flows From Financing Activities: | ||
Dividends on preferred stock | (1) | (1) |
Short-term debt, net | 250 | 0 |
Money pool borrowings, net | 0 | (19) |
Maturities of long-term debt | (400) | 0 |
Issuances of long-term debt | 499 | 449 |
Capital contributions from parent | 0 | 145 |
Redemption of preferred stock | 0 | (13) |
Debt issuance costs | (5) | (6) |
Other | 0 | (13) |
Net cash provided by financing activities | 343 | 542 |
Net change in cash, cash equivalents, and restricted cash | 33 | (25) |
Cash, cash equivalents, and restricted cash at beginning of year | 133 | 147 |
Cash, cash equivalents, and restricted cash at end of period | $ 166 | $ 122 |
Consolidated Statement of Stock
Consolidated Statement of Stockholders' Equity - USD ($) $ in Millions | Total | Common Stock | Other Paid-in Capital | Retained Earnings | Deferred Retirement Benefit Costs | Accumulated Other Comprehensive Income | Total Ameren Corporation Shareholders' Equity | Noncontrolling Interests | Union Electric Company | Union Electric Company Common Stock | Union Electric Company Other Paid-in Capital | Union Electric Company Preferred Stock | Union Electric Company Retained Earnings | Ameren Illinois Company | Ameren Illinois Company Common Stock | Ameren Illinois Company Other Paid-in Capital | Ameren Illinois Company Preferred Stock | Ameren Illinois Company Retained Earnings |
Beginning of period at Dec. 31, 2020 | $ 6,179 | $ 2,757 | $ (1) | $ 142 | $ 2,518 | $ 2,101 | $ 2,652 | $ 62 | $ 2,252 | |||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Settlement of forward sale agreement through common shares issuance | 113 | |||||||||||||||||
Shares issued under the ATM program | 148 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 36 | |||||||||||||||||
Stock-based compensation activity | 7 | |||||||||||||||||
Capital contributions from parent | $ 183 | 183 | $ 145 | 145 | ||||||||||||||
Net income | $ 869 | 536 | 536 | 315 | 315 | |||||||||||||
Net income attributable to Ameren common shareholders | 865 | 865 | ||||||||||||||||
Dividends on common stock | (423) | |||||||||||||||||
Preferred stock dividends | (3) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | 1 | 1 | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (4) | 4 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (4) | |||||||||||||||||
Redemptions of preferred stock | (13) | (13) | ||||||||||||||||
Common stock shares outstanding at beginning of year (in shares) at Dec. 31, 2020 | 253,300,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under forward sale agreement (in shares) | 1,600,000 | |||||||||||||||||
Stock Issued During Period, Shares, New Issues | 1,800,000 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 400,000 | |||||||||||||||||
Shares issued for stock-based compensation (in shares) | 500,000 | |||||||||||||||||
Common stock shares outstanding at end of period (in shares) at Sep. 30, 2021 | 257,600,000 | |||||||||||||||||
End of period at Sep. 30, 2021 | $ 9,814 | $ 3 | 6,483 | 3,199 | 0 | $ 0 | 129 | $ 511 | 2,701 | $ 80 | 2,634 | $ 0 | 2,797 | 49 | 2,566 | |||
Shareholders' equity, end of year at Sep. 30, 2021 | $ 9,685 | 5,926 | 5,412 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share (in dollars per share) | $ 1.65 | |||||||||||||||||
Beginning of period at Jun. 30, 2021 | 6,436 | 2,915 | (1) | 129 | 2,701 | 2,259 | 2,722 | 49 | 2,487 | |||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Settlement of forward sale agreement through common shares issuance | 0 | |||||||||||||||||
Shares issued under the ATM program | 27 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 12 | |||||||||||||||||
Stock-based compensation activity | 8 | |||||||||||||||||
Capital contributions from parent | 0 | 75 | ||||||||||||||||
Net income | $ 426 | 376 | 376 | 79 | 79 | |||||||||||||
Net income attributable to Ameren common shareholders | 425 | 425 | ||||||||||||||||
Dividends on common stock | (141) | |||||||||||||||||
Preferred stock dividends | (1) | 0 | ||||||||||||||||
Change in deferred retirement benefit costs | 1 | 1 | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (1) | 1 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (1) | |||||||||||||||||
Redemptions of preferred stock | 0 | 0 | ||||||||||||||||
Common stock shares outstanding at beginning of year (in shares) at Jun. 30, 2021 | 257,100,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under forward sale agreement (in shares) | 0 | |||||||||||||||||
Stock Issued During Period, Shares, New Issues | 400,000 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 100,000 | |||||||||||||||||
Shares issued for stock-based compensation (in shares) | 0 | |||||||||||||||||
Common stock shares outstanding at end of period (in shares) at Sep. 30, 2021 | 257,600,000 | |||||||||||||||||
End of period at Sep. 30, 2021 | $ 9,814 | 3 | 6,483 | 3,199 | 0 | 0 | 129 | 511 | 2,701 | 80 | 2,634 | 0 | 2,797 | 49 | 2,566 | |||
Shareholders' equity, end of year at Sep. 30, 2021 | 9,685 | 5,926 | 5,412 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share (in dollars per share) | $ 0.55 | |||||||||||||||||
Beginning of period at Dec. 31, 2021 | $ 9,829 | 6,502 | 3,182 | 13 | 129 | 2,725 | 2,595 | 2,914 | 49 | 2,677 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Settlement of forward sale agreement through common shares issuance | 0 | |||||||||||||||||
Shares issued under the ATM program | 0 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 37 | |||||||||||||||||
Stock-based compensation activity | 9 | |||||||||||||||||
Capital contributions from parent | 0 | 0 | 0 | 0 | ||||||||||||||
Net income | 915 | $ 550 | 550 | $ 376 | 376 | |||||||||||||
Net income attributable to Ameren common shareholders | 911 | 911 | ||||||||||||||||
Dividends on common stock | (457) | |||||||||||||||||
Preferred stock dividends | (3) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | 1 | 1 | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (4) | 4 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (4) | |||||||||||||||||
Redemptions of preferred stock | 0 | 0 | ||||||||||||||||
Common stock shares outstanding at beginning of year (in shares) at Dec. 31, 2021 | 257,700,000 | 102,100,000 | 25,500,000 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under forward sale agreement (in shares) | 0 | |||||||||||||||||
Stock Issued During Period, Shares, New Issues | 0 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 400,000 | |||||||||||||||||
Shares issued for stock-based compensation (in shares) | 400,000 | |||||||||||||||||
Common stock shares outstanding at end of period (in shares) at Sep. 30, 2022 | 258,500,000 | 102,100,000 | 25,500,000 | |||||||||||||||
End of period at Sep. 30, 2022 | $ 10,330 | 3 | 6,548 | 3,636 | 14 | 14 | 129 | 511 | 2,725 | 80 | 3,142 | 0 | 2,914 | 49 | 3,052 | |||
Shareholders' equity, end of year at Sep. 30, 2022 | $ 10,201 | 10,201 | $ 6,458 | $ 6,015 | ||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share (in dollars per share) | $ 1.77 | |||||||||||||||||
Beginning of period at Jun. 30, 2022 | 6,527 | 3,336 | 14 | 129 | 2,725 | 2,745 | 2,914 | 49 | 2,949 | |||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Settlement of forward sale agreement through common shares issuance | 0 | |||||||||||||||||
Shares issued under the ATM program | 0 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 12 | |||||||||||||||||
Stock-based compensation activity | 9 | |||||||||||||||||
Capital contributions from parent | 0 | 0 | ||||||||||||||||
Net income | $ 453 | $ 398 | 398 | $ 103 | 103 | |||||||||||||
Net income attributable to Ameren common shareholders | 452 | 452 | ||||||||||||||||
Dividends on common stock | (152) | |||||||||||||||||
Preferred stock dividends | (1) | 0 | ||||||||||||||||
Change in deferred retirement benefit costs | 0 | 0 | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (1) | 1 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (1) | |||||||||||||||||
Redemptions of preferred stock | 0 | 0 | ||||||||||||||||
Common stock shares outstanding at beginning of year (in shares) at Jun. 30, 2022 | 258,400,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under forward sale agreement (in shares) | 0 | |||||||||||||||||
Stock Issued During Period, Shares, New Issues | 0 | |||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 100,000 | |||||||||||||||||
Shares issued for stock-based compensation (in shares) | 0 | |||||||||||||||||
Common stock shares outstanding at end of period (in shares) at Sep. 30, 2022 | 258,500,000 | 102,100,000 | 25,500,000 | |||||||||||||||
End of period at Sep. 30, 2022 | $ 10,330 | $ 3 | $ 6,548 | $ 3,636 | $ 14 | $ 14 | $ 129 | $ 511 | $ 2,725 | $ 80 | $ 3,142 | $ 0 | $ 2,914 | $ 49 | $ 3,052 | |||
Shareholders' equity, end of year at Sep. 30, 2022 | $ 10,201 | $ 10,201 | $ 6,458 | $ 6,015 | ||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share (in dollars per share) | $ 0.59 |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 9 Months Ended |
Sep. 30, 2022 | |
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 whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. Ameren has other subsidiaries that conduct other activities, such as providing shared services. • Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri. • Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois. • ATXI operates a FERC rate-regulated electric transmission business in the MISO. Due to a change in customer behavior and certain business practices resulting from the COVID-19 pandemic, there has been a shift in sales volumes by customer class at both Ameren Missouri and Ameren Illinois, which began in 2020, with an increase in residential sales, and a decrease in commercial and industrial sales. While our electric sales volumes in the first nine months of 2022, excluding the estimated effects of weather and customer energy-efficiency programs, were comparable to the same period in 2021 and, at Ameren Missouri, were comparable to pre-pandemic levels, Ameren Illinois’ sales volumes remain below pre-pandemic levels. However, revenues from Ameren Illinois’ electric distribution business, residential and small nonresidential customers of Ameren Illinois’ natural gas distribution business, and Ameren Illinois’ and ATXI’s electric transmission businesses are decoupled from changes in sales volumes. Earnings at Ameren Missouri and those associated with Ameren Illinois’ large nonresidential natural gas customers are exposed to such changes. Further effects of the COVID-19 pandemic on our results of operations, financial position, and liquidity in subsequent periods will depend on its severity and longevity, future regulatory or legislative actions with respect thereto, and the resulting impact on business, economic, and capital market conditions. Ameren’s and Ameren Missouri’s financial statements are prepared on a consolidated basis and therefore include the accounts of their majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Missouri’s subsidiaries were created for the ownership of renewable generation projects. Ameren Illinois has no subsidiaries. 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 reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. The results of operations for 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 accompanying notes included in the Form 10-K. Variable Interest Entities As of September 30, 2022, and December 31, 2021, Ameren had unconsolidated variable interests as a limited partner in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $58 million and $56 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Any earnings or losses related to these investments are included in “Other Income, Net” on Ameren’s consolidated statement of income and comprehensive income. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of September 30, 2022, the maximum exposure to loss related to these variable interests is limited to the investment in these partnerships of $58 million plus associated outstanding funding commitments of $21 million. COLI Ameren and Ameren Illinois have COLI, which is recorded at the net cash surrender value. The net cash surrender value is the amount that can be realized under the insurance policies at the balance sheet date. As of September 30, 2022, the cash surrender value of COLI at Ameren and Ameren Illinois was $239 million (December 31, 2021 – $278 million) and $116 million (December 31, 2021 – $117 million), respectively, while total borrowings against the policies were $108 million (December 31, 2021 – $109 million) at both Ameren and Ameren Illinois. Ameren and Ameren Illinois have the right to offset the borrowings against the cash surrender value of the policies and, consequently, present the net asset in “Other assets” on their respective balance sheets. The net cash surrender value of Ameren’s COLI is affected by the investment performance of a separate account in which Ameren holds a beneficial interest. |
Rate And Regulatory Matters
Rate And Regulatory Matters | 9 Months Ended |
Sep. 30, 2022 | |
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 legal proceedings. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K for additional information and a summary of our regulatory frameworks. We are unable to predict the ultimate outcome of these matters, the timing of final decisions of the various agencies and courts, or the impact on our results of operations, financial position, or liquidity. Missouri 2022 Electric Service Regulatory Rate Review In August 2022, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $316 million. The electric rate increase request is based on a 10.2% ROE, a capital structure composed of 51.9% common equity, a rate base of $11.6 billion, and a test year ended March 31, 2022, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2022. Ameren Missouri’s request includes the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable energy standard costs that the MoPSC previously authorized in earlier electric rate orders, as well as the use of an electric property tax tracker allowed under Missouri Senate Bill 745 discussed below. In October 2022, Ameren Missouri also requested the use of a tracker for variances between actual income tax benefits and costs resulting from the IRA and those amounts included in customer rates, which would be considered for recovery or refund in a future electric regulatory rate review. For additional information regarding the IRA, see Note 12 – Income Taxes. The electric rate increase request reflects the following: • increased infrastructure investments made under Ameren Missouri’s Smart Energy Plan, including increased cost of capital and depreciation expense; • increased net fuel expense due to reduced off system sales, primarily driven by expected reduced operations at the Rush Island Energy Center; and • extending the retirement date of the Sioux Energy Center from 2028 to 2030, consistent with Ameren Missouri’s 2022 Change to the 2020 IRP, in order to support reliability during the transition to clean energy generation. In connection with the planned accelerated retirement of the Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute. As such, Ameren Missouri did not request a change in the depreciation rates related to the Rush Island Energy Center in this electric service regulatory rate review. The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by June 2023 and new rates effective by July 2023. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient for Ameren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect. Missouri Senate Bill 745 In June 2022, Missouri Senate Bill 745 was enacted and became effective on August 28, 2022. The law extended Ameren Missouri’s PISA election through December 2028 and allows for an additional extension through December 2033 if requested by Ameren Missouri and approved by the MoPSC, among other things. The law established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1, 2024, and will be based on the revenue requirement established in the immediately preceding rate order. The current rate limitation, which is effective through 2023, is a 2.85% cap on the compound annual growth rate in the average overall customer rate per kilowatthour, based on the electric rates that became effective in April 2017, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 2018 MoPSC order. The law also established electric and natural gas property tax trackers that allow Ameren Missouri to defer the difference between actual property taxes incurred and related taxes included in customer rates as a regulatory asset or regulatory liability, with the difference expected to be reflected in rate base in a subsequent rate order. Upon the effective date of the law, Ameren Missouri began deferring amounts under these trackers. The deferrals were immaterial as of September 30, 2022. Solar Generation Facilities In February 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 150-MW solar generation facility, which is expected to be located in southeastern Illinois and, if approved by the MoPSC, to serve customers under Ameren Missouri’s Renewable Solutions Program discussed below. In June 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 200-MW solar generation facility, which is expected to be located in central Missouri and support Ameren Missouri’s compliance with the state of Missouri’s requirement of achieving 15% of retail sales from renewable energy sources, of which 2% must be derived from solar energy sources. The acquisitions are aligned with the 2022 Change to the 2020 IRP, which Ameren Missouri filed with the MoPSC in June 2022, and are subject to certain conditions, including the issuance of certificates of convenience and necessity by the MoPSC, obtaining MISO transmission interconnection agreements, and approval by the FERC. In July 2022, Ameren Missouri filed for certificates of convenience and necessity with the MoPSC for both facilities and expects decisions by March 2023 and April 2023 for the 200-MW facility and the 150-MW facility, respectively. Depending on the timing of regulatory approvals and the impact of potential sourcing issues resulting from a United States Department of Commerce investigation of solar panels imported from four Southeast Asian countries initiated in late March 2022 and the detention of certain solar panels sourced from China as a result of the Uyghur Forced Labor Prevention Act that was passed in December 2021, the projects could be completed as early as the fourth quarter of 2024. Renewable Solutions Program In July 2022, Ameren Missouri filed a request with the MoPSC seeking approval of its Renewable Solutions Program and a tariff related to participation in the program. The program would allow certain commercial, industrial, and governmental customers to receive up to 100% of their energy from renewable resources. Based on customer contracts, the program would enable Ameren Missouri to supply renewable solar energy generated by the 150-MW facility discussed above to customers that enroll in the program. Ameren Missouri expects a decision from the MoPSC by April 2023. MoPSC Staff Review of Planned Rush Island Energy Center Retirement In February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center as a result of the NSR and Clean Air Act Litigation discussed in Note 9 – Commitments and Contingencies. The MoPSC staff’s review includes potential impacts on the reliability and cost of Ameren Missouri’s service to its customers; Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement; and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, which is expected to be addressed in the 2022 electric service regulatory rate review, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement of the Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. Ameren Missouri is unable to predict the results of this matter. Results of the review could be used in other MoPSC proceedings, which could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. MEEIA In August 2022, the MoPSC issued an order approving Ameren Missouri’s energy savings results for the 2021 program year of the MEEIA 2019 program. As a result of this order and a MoPSC order issued in September 2021, Ameren Missouri recognized revenues of $12 million and $9 million in the third quarter of 2022 and 2021, respectively. December 2021 MoPSC Electric and Natural Gas Rate Orders In December 2021, the MoPSC issued orders in Ameren Missouri’s 2021 electric service and natural gas delivery service regulatory rate reviews. The new electric and natural gas rates approved by these orders became effective on February 28, 2022. Illinois MYRP ROE Performance Metrics Under an MYRP, the ROE approved by the ICC would be subject to annual adjustments during the four-year period based on certain performance metrics, with aggregate symmetrical performance-based ROE incentives and penalties ranging from 20 to 60 basis points annually. In September 2022, the ICC issued an order approving the performance metrics to be used by Ameren Illinois in determining ROE incentives and penalties. The ICC order approved total ROE incentives and penalties of 24 basis points, allocated among seven approved performance metrics. These performance metrics include improvements in service reliability in both the frequency and duration of outages, a reduction in peak loads, an increased percentage of spend with diverse suppliers, a reduction in disconnections for certain customers, and improved timeliness in response to customer requests for interconnection of distributed energy resources. The ROE incentives and penalties would apply annually from 2024 through 2027 if, as planned, Ameren Illinois elects to file an MYRP by January 20, 2023. Electric Distribution Service Rates Under IEIMA In April 2022, Ameren Illinois filed its annual electric distribution service performance-based formula rate update with the ICC to be used for 2023 rates. In July 2022, Ameren Illinois filed a revised request seeking to increase its annual revenues for electric distribution service by $84 million. The updated request reflects an increase to the annual performance-based formula rate based on 2021 actual recoverable costs and expected net plant additions for 2022, an increase to include the 2021 revenue requirement reconciliation adjustment including a capital structure composed of 54% common equity, and a decrease for the conclusion of the 2020 revenue requirement reconciliation adjustment, which will be fully collected from customers in 2022, consistent with the ICC’s December 2021 annual update filing order. In August 2022, the ICC staff submitted its calculation of the revenue requirement included in Ameren Illinois’ update filing, recommending a $61 million increase in Ameren Illinois’ electric distribution service rates, which is based on a capital structure composed of 50% common equity. An ICC decision in this proceeding is required by December 2022, with new rates effective in January 2023. Electric Customer Energy-Efficiency Investments In June 2022, Ameren Illinois filed its annual electric customer energy-efficiency formula rate update to increase its rates by $17 million with the ICC. In August 2022, the ICC staff submitted a calculation of the revenue requirement included in Ameren Illinois’ filing, recommending a $15 million increase in rates. An ICC decision in this proceeding is required by December 2022, with new rates effective January 2023. In June 2022, the ICC issued an order approving Ameren Illinois’ revised energy-efficiency plan that includes annual investments in electric energy-efficiency programs of approximately $120 million per year through 2025, which reflects the increased level of annual investments allowed under the IETL. The ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs. The electric energy-efficiency program investments and the return on those investments are collected from customers through a rider and are not recovered through the electric distribution service performance-based formula ratemaking framework. Illinois Senate Bill 3866 In May 2022, Illinois Senate Bill 3866 was enacted and became effective. This legislation makes certain amendments to the IETL, including amendments to increase the level of funding for the Energy Transition Assistance Fund. As a result of this legislation, Ameren Illinois expects to collect up to $50 million annually related to this fund, beginning in January 2023. Funds collected by Ameren Illinois will be remitted in the month following collection to an Illinois state agency, with no impact to results of operations. RTO Cost-Benefit Study In July 2022, an Illinois law prohibiting the state’s oversight of certain electric utilities’ choice of RTO membership ceased to be effective. Given the change in law and the high prices resulting from MISO’s April 2022 capacity auction, the ICC issued an order requiring Ameren Illinois to perform a cost-benefit study of continued participation in the MISO compared to participation in PJM Interconnection LLC, another RTO. The cost-benefit study will examine the impacts of participation in each RTO, including reliability, resiliency, affordability, and environmental impacts, among other things, for a period of five QIP Reconciliation Hearing In March 2020, Ameren Illinois filed its annual request with the ICC for a reconciliation hearing to determine the accuracy and prudence of natural gas capital investments recovered under the QIP rider during 2019. In August 2021, the Illinois Attorney General’s office challenged the recovery of capital investments that were made during 2019, alleging that the ICC should disallow approximately $70 million in natural gas capital investments as improper and imprudent, providing a potential over-recovery of approximately $3 million in 2019. In August and December 2021, the ICC staff filed testimony that supports the prudence and reasonableness of the capital investments made during 2019. Ameren Illinois’ 2019 QIP rate recovery request under review by the ICC is within the rate increase limitations allowed by law. The ICC is under no deadline to issue an order in this proceeding. Federal Transmission Formula Rate Revisions In February 2020, the MISO, on behalf of Ameren Missouri, Ameren Illinois, and ATXI, filed requests with the FERC to revise each company’s transmission formula rate calculations with respect to the calculation used for materials and supplies inventories included in rate base. In May 2020, the FERC issued orders approving the revisions prospectively. In addition, the FERC declined to order refunds for earlier periods, as requested by intervenors in Ameren Illinois’ filing, but directed its audit staff to review historical rate recovery in connection with an ongoing FERC audit. Separately, in March 2021, the FERC issued an order related to an intervenor challenge to Ameren Illinois’ 2020 transmission formula rate update. As a result of this order, in March 2021, Ameren Illinois recorded a regulatory liability of $9 million, largely as a reduction of electric operating revenues, to reflect expected refunds, including interest, primarily related to the historical rate recovery of materials and supplies inventories included in rate base. The refund amount was reflected in rates as of January 2022 and will be refunded to customers by the end of 2022. Ameren Missouri, Ameren Illinois, and ATXI filed appeals of the FERC’s May 2020 and March 2021 orders, and related FERC orders denying requests for rehearing, to the United States Court of Appeals for the District of Columbia Circuit. In January 2022, the appeals were consolidated by the court. The court is under no deadline to address the appeal. Regardless of the outcome of the appeal, the impact of the May 2020 and March 2021 orders is not expected to be material to Ameren’s, Ameren Missouri’s, or Ameren Illinois’ results of operations, financial position, or liquidity. FERC Complaint Cases Since November 2013, the allowed base ROE for FERC-regulated transmission rate base under the MISO tariff has been subject to customer complaint cases and has been changed by various FERC orders. In May 2020, the FERC issued an order, which set the allowed base ROE to 10.02%, and required refunds, with interest, for the periods November 2013 to February 2015 and from late September 2016 forward. Ameren and Ameren Illinois paid these refunds, including interest, by March 31, 2022. In June and July 2020, Ameren Missouri, Ameren Illinois, and ATXI, as well as various customers, petitioned the United States Court of Appeals for the District of Columbia Circuit for review of the May 2020 order, challenging certain aspects of the new ROE methodology established. The petition filed by Ameren Missouri, Ameren Illinois, and ATXI challenged the refunds required for the period from September 2016 to May 2020. In August 2022, the court issued a ruling that granted the customers’ petition for review, vacated the FERC’s previous MISO ROE-determining orders, and remanded the proceedings to the FERC. The currently allowed base ROE of 10.02% will remain effective for customer billings, but subject to refund if the base ROE is changed by the FERC in a future order. The FERC is under no deadline to issue an order related to these proceedings. A 50 basis point change in the FERC-allowed ROE would affect Ameren’s and Ameren Illinois’ annual revenue by an estimated $17 million and $11 million, respectively, based on each company’s 2022 projected rate base. |
Short-Term Debt And Liquidity
Short-Term Debt And Liquidity | 9 Months Ended |
Sep. 30, 2022 | |
Debt Disclosure [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, and, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, in the Form 10-K for a description of our indebtedness provisions and other covenants as well as a description of money pool arrangements. Short-term Borrowings The Missouri Credit Agreement and the Illinois Credit Agreement are available to support issuances under Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper programs, respectively, subject to borrowing sublimits, and the issuance of letters of credit. As of September 30, 2022, based on commercial paper outstanding and letters of credit issued under the Credit Agreements, along with cash and cash equivalents, the net liquidity available to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, was $1.1 billion. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of September 30, 2022. As of September 30, 2022, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were 59%, 49%, and 45% for Ameren, Ameren Missouri, and Ameren Illinois, respectively. The following table presents commercial paper outstanding, net of issuance discounts, as of September 30, 2022, and December 31, 2021. There were no borrowings outstanding under the Credit Agreements as of September 30, 2022, or December 31, 2021. September 30, 2022 December 31, 2021 Ameren (parent) $ 690 $ 277 Ameren Missouri 178 165 Ameren Illinois 353 103 Ameren consolidated $ 1,221 $ 545 The following table summarizes the activity and relevant interest rates for Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper issuances and borrowings under the Credit Agreements in the aggregate for the nine months ended September 30, 2022 and 2021: Ameren Ameren Ameren Ameren 2022 Average daily amount outstanding $ 439 $ 253 $ 99 $ 791 Weighted-average interest rate 1.58 % 1.16 % 1.77 % 1.47 % Peak amount outstanding during period (a) $ 690 $ 539 $ 354 $ 1,222 Peak interest rate 3.55 % 3.55 % 3.60 % 3.60 % 2021 Average daily amount outstanding $ 404 $ 121 $ 140 $ 665 Weighted-average interest rate 0.23 % 0.22 % 0.22 % 0.22 % Peak amount outstanding during period (a) $ 650 $ 546 $ 485 $ 1,134 Peak interest rate 0.33 % 0.25 % 0.25 % 0.33 % (a) The timing of peak outstanding commercial paper issuances and borrowings under the Credit Agreements varies by company. Therefore, the sum of individual company peak amounts may not equal the Ameren consolidated peak for the period. 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. The average interest rate for borrowings under the utility money pool for the three and nine months ended September 30, 2022, was 2.48% and 1.29%, respectively (2021 – 0.06% and 0.17%, respectively). See Note 8 – Related-party Transactions for the amount of interest income and expense from the utility money pool arrangements recorded by Ameren Missouri and Ameren Illinois for the three and nine months ended September 30, 2022 and 2021. |
Long-Term Debt And Equity Finan
Long-Term Debt And Equity Financings | 9 Months Ended |
Sep. 30, 2022 | |
Long-Term Debt And Equity Financings [Abstract] | |
LONG-TERM DEBT AND EQUITY FINANCINGS | LONG-TERM DEBT AND EQUITY FINANCINGS Ameren For the three and nine months ended September 30, 2022, Ameren issued a total of 0.1 million and 0.4 million shares of common stock, respectively, under its DRPlus and 401(k) plan, and received proceeds of $4 million and $29 million, respectively, and had a receivable of $8 million as of September 30, 2022. In addition, in the first quarter of 2022, Ameren issued 0.4 million shares of common stock valued at $31 million upon the settlement of stock-based compensation awards. In May 2021, Ameren entered into an equity distribution sales agreement pursuant to which Ameren may offer and sell from time to time up to $750 million of its common stock through an ATM program, which includes the ability to enter into forward sales agreements. There were no shares issued under the ATM program for the three and nine months ended September 30, 2022. As of September 30, 2022, Ameren had substantially utilized the available capacity under the ATM program, which takes into account the forward sale agreements discussed below. Ameren has entered into multiple forward sale agreements under the ATM program with various counterparties relating to 6.6 million shares of common stock. Related to the forward sale agreements outstanding as of September 30, 2022, these agreements can be settled at Ameren’s discretion on or prior to dates ranging from May 3, 2023 to March 8, 2024. On a settlement date or dates, if Ameren elects to physically settle a forward sale agreement, Ameren will issue shares of common stock to the counterparties at the then-applicable forward sale price. The initial forward sale price for the agreements ranged from $86.35 to $94.80 with an average initial forward sale price of $90.31. Each initial forward sale price is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75 basis points, and will be subject to decrease on certain dates specified in the forward sale agreements by specified amounts related to expected dividends on shares of the common stock during the term of the forward sale agreements. If the overnight bank funding rate is less than the spread on any day, the interest rate factor will result in a reduction of the forward sale price. The forward sale agreements will be physically settled unless Ameren elects to settle in cash or to net share settle. At September 30, 2022, Ameren could have settled the forward sale agreements with physical delivery of 6.6 million shares of common stock to the respective counterparties in exchange for cash of $587 million. Alternatively, the forward sale agreements could have also been settled at September 30, 2022, with the counterparties delivering approximately $58 million of cash or approximately 0.7 million shares of common stock to Ameren. In connection to the forward sale agreements, the various counterparties, or their affiliates, borrowed from third parties and sold 6.6 million shares of common stock. The gross sales price of these shares totaled $600 million. In connection with such sales, the counterparties were deemed to have received commissions of $6 million. Ameren has not received any proceeds from such sales of borrowed shares. The forward sale agreements have been classified as equity transactions. Ameren Missouri In April 2022, Ameren Missouri issued $525 million of 3.90% first mortgage bonds due April 2052, with interest payable semiannually on April 1 and October 1 of each year, beginning October 1, 2022. Ameren Missouri received net proceeds of $519 million, which were used to repay short-term debt and for near-term capital expenditures. Ameren Missouri intends to allocate an amount equal to the proceeds, after expenses, to sustainability projects meeting certain eligibility criteria. Ameren Illinois In August 2022, Ameren Illinois issued $500 million of 3.85% first mortgage bonds due September 2032, with interest payable semiannually on March 1 and September 1 of each year, beginning March 1, 2023. Ameren Illinois received net proceeds of $496 million, which were used to repay $400 million principal amount of its 2.70% senior secured notes that matured in September 2022 and short-term debt. ATXI In November 2021, pursuant to a note purchase agreement, ATXI agreed to issue $95 million of its 2.96% senior unsecured notes due 2052, with interest payable semiannually on February 25 and August 25 of each year, beginning February 25, 2023, through a private placement offering exempt from registration under the Securities Act of 1933, as amended. In August 2022, ATXI issued the notes and received net proceeds of $95 million, which were used to refinance the remaining portion of an intercompany long-term note with Ameren (parent), repay $50 million in principal amount of its 3.43% senior unsecured notes in August 2022, and repay short-term debt. Indenture Provisions and Other Covenants See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, in the Form 10-K for a description of our indenture provisions and other covenants, as well as restrictions on the payment of dividends. At September 30, 2022, the Ameren Companies were in compliance with the provisions and covenants contained in their indentures and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreements. Off-balance-sheet Arrangements At September 30, 2022, none of the Ameren Companies had any significant off-balance-sheet financing arrangements, other than variable interest entities and the multiple forward sale agreements under the ATM program relating to common stock. See Note 1 – Summary of Significant Accounting Policies for further detail concerning variable interest entities. |
Other Income, Net
Other Income, Net | 9 Months Ended |
Sep. 30, 2022 | |
Other Nonoperating Income (Expense) [Abstract] | |
OTHER INCOME, NET | OTHER INCOME, NET The following table presents the components of “Other Income, Net” in the Ameren Companies’ statements of income for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren: Allowance for equity funds used during construction $ 12 $ 14 $ 31 $ 30 Interest income on industrial development revenue bonds 6 7 18 19 Non-service cost components of net periodic benefit income (a) 45 34 138 102 Miscellaneous income 5 1 14 7 Earnings (losses) related to equity method investments (3) 2 1 8 Donations (1) (1) (5) (5) Miscellaneous expense (6) (1) (17) (10) Total Other Income, Net $ 58 $ 56 $ 180 $ 151 Ameren Missouri: Allowance for equity funds used during construction $ 7 $ 7 $ 17 $ 17 Interest income on industrial development revenue bonds 6 7 18 19 Non-service cost components of net periodic benefit income (a) 13 13 41 41 Miscellaneous income 2 2 5 3 Donations — — (2) (1) Miscellaneous expense (3) (2) (7) (5) Total Other Income, Net $ 25 $ 27 $ 72 $ 74 Ameren Illinois: Allowance for equity funds used during construction $ 5 $ 7 $ 14 $ 13 Non-service cost components of net periodic benefit income 21 13 63 41 Miscellaneous income 4 — 9 4 Donations (1) (1) (3) (4) Miscellaneous expense (3) — (8) (5) Total Other Income, Net $ 26 $ 19 $ 75 $ 49 (a) For the three and nine months ended September 30, 2022, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $5 million and $16 million, respectively, due to a regulatory tracking mechanism for the difference between the level of such costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. The deferral was $(3) million and $(6) million for both the three and nine months ended September 30, 2021, respectively. See Note 11– Retirement Benefits for additional information. |
Derivative Financial Instrument
Derivative Financial Instruments | 9 Months Ended |
Sep. 30, 2022 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
DERIVATIVE FINANCIAL INSTRUMENTS | DERIVATIVE FINANCIAL INSTRUMENTS We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following: • an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices; • market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; • actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays; and • actual off-system sales revenues that differ from anticipated revenues. 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. All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. 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. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting. If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether the resulting gains or losses 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 liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and liabilities are probable of recovery, or refund, through future rates charged to customers. Regulatory assets and 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 September 30, 2022, and December 31, 2021, all contracts that met the definition of a derivative and were not eligible for the NPNS exception received regulatory deferral. Cash flows for all derivative financial instruments are classified in cash flows from operating activities. The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of September 30, 2022, and December 31, 2021. As of September 30, 2022, these contracts extended through October 2024, October 2027, May 2032 and March 2024 for fuel oils, natural gas, power and uranium, respectively: Quantity (in millions) September 30, 2022 December 31, 2021 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) 19 — 19 30 — 30 Natural gas (in mmbtu) 43 144 187 35 144 179 Power (in MWhs) 2 6 8 6 6 12 Uranium (pounds in thousands) 406 — 406 586 — 586 The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Balance Sheet Location Ameren Ameren Ameren Ameren Ameren Ameren Fuel oils Other current assets 12 — 12 8 — 8 Other assets 3 — 3 5 — 5 Natural gas Mark-to-market derivative assets (a) 57 (a) (a) 28 (a) Other current assets 14 — 71 7 — 35 Other assets 13 21 34 5 13 18 Power Mark-to-market derivative assets (a) 11 (a) (a) — (a) Other current assets 28 — 39 23 — 23 Other assets — 5 5 — — — Uranium Other current assets 2 — 2 — — — Other assets 1 — 1 1 — 1 Total assets $ 73 $ 94 $ 167 $ 49 $ 41 $ 90 Fuel oils Other deferred credits and liabilities 1 — 1 — — — Natural gas Mark-to-market derivative liabilities 2 (a) (a) 2 (a) (a) Other current liabilities — 9 11 — 6 8 Other deferred credits and liabilities 1 3 4 1 2 3 Power Mark-to-market derivative liabilities 111 (a) (a) 50 (a) (a) Other current liabilities — — 111 — 9 59 Other deferred credits and liabilities 14 36 50 23 108 131 Uranium Mark-to-market derivative liabilities — (a) (a) 1 (a) (a) Other current liabilities — — — — — 1 Total liabilities $ 129 $ 48 $ 177 $ 77 $ 125 $ 202 (a) Balance sheet line item not applicable to registrant. 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. 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 September 30, 2022, and December 31, 2021: 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 September 30, 2022 Assets: Ameren Missouri $ 73 $ 18 $ 2 $ 53 Ameren Illinois 94 13 1 80 Ameren $ 167 $ 31 $ 3 $ 133 Liabilities: Ameren Missouri $ 129 $ 18 $ 99 $ 12 Ameren Illinois 48 13 — 35 Ameren $ 177 $ 31 $ 99 $ 47 December 31, 2021 Assets: Ameren Missouri $ 49 $ 15 $ — $ 34 Ameren Illinois 41 4 — 37 Ameren $ 90 $ 19 $ — $ 71 Liabilities: Ameren Missouri $ 77 $ 15 $ 47 $ 15 Ameren Illinois 125 4 — 121 Ameren $ 202 $ 19 $ 47 $ 136 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Current collateral assets” and “Other assets” on the balance sheet for Ameren and Ameren Missouri and “Other current assets” and “Other assets” for Ameren Illinois. 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. As of September 30, 2022, if counterparty groups were to fail completely to perform on contracts, Ameren, Ameren Missouri, and Ameren Illinois’ maximum exposure related to derivative assets, predominantly from financial institutions, was $142 million, $55 million, and $87 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 September 30, 2022, 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 $124 million, $43 million, and $81 million, respectively. Certain of our derivative instruments contain collateral provisions tied to the Ameren Companies’ credit ratings. If our credit ratings were downgraded below investment grade, or if a counterparty with reasonable grounds for uncertainty regarding our ability to satisfy an obligation requested adequate assurance of performance, additional collateral postings might be required. The additional collateral required is the net liability position allowed under master netting arrangements or similar agreements, assuming (1) the credit risk-related contingent features underlying these arrangements were triggered and (2) those counterparties with rights to do so requested collateral. As of September 30, 2022, the aggregate fair value of derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require were each immaterial to Ameren, Ameren Missouri, and Ameren Illinois. |
Fair Value Measurements
Fair Value Measurements | 9 Months Ended |
Sep. 30, 2022 | |
Fair Value Disclosures [Abstract] | |
Fair Value Disclosures | FAIR VALUE MEASUREMENTS Fair value is defined as the 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. Fair value measurements are classified in three levels based on the fair value hierarchy as defined by GAAP. See Note 8 – Fair Value Measurements under Part II, Item 8, of the Form 10-K for information related to hierarchy levels and valuation techniques. We consider nonperformance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g., collateral). 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 material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in the three and nine months ended September 30, 2022 or 2021. At September 30, 2022, and December 31, 2021, the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois. The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Ameren Missouri Derivative assets – commodity contracts: Fuel oils $ 13 $ — $ 2 $ 15 $ 13 $ — $ — $ 13 Natural gas 1 26 — 27 — 12 — 12 Power 9 — 19 28 10 — 13 23 Uranium — — 3 3 — — 1 1 Total derivative assets – commodity contracts $ 23 $ 26 $ 24 $ 73 $ 23 $ 12 $ 14 $ 49 Nuclear decommissioning trust fund: Equity securities: U.S. large capitalization $ 574 $ — $ — $ 574 $ 824 $ — $ — $ 824 Debt securities: U.S. Treasury and agency securities — 148 — 148 — 141 — 141 Corporate bonds — 115 — 115 — 131 — 131 Other — 64 — 64 — 56 — 56 Total nuclear decommissioning trust fund $ 574 $ 327 $ — $ 901 (a) $ 824 $ 328 $ — $ 1,152 (a) Total Ameren Missouri $ 597 $ 353 $ 24 $ 974 $ 847 $ 340 $ 14 $ 1,201 Ameren Illinois Derivative assets – commodity contracts: Natural gas $ 6 $ 65 $ 7 $ 78 $ 1 $ 33 $ 7 $ 41 Power — — 16 16 — — — — Total Ameren Illinois $ 6 $ 65 $ 23 $ 94 $ 1 $ 33 $ 7 $ 41 Ameren Derivative assets – commodity contracts (b) $ 29 $ 91 $ 47 $ 167 $ 24 $ 45 $ 21 $ 90 Nuclear decommissioning trust fund (c) 574 327 — 901 (a) 824 328 — 1,152 (a) Total Ameren $ 603 $ 418 $ 47 $ 1,068 $ 848 $ 373 $ 21 $ 1,242 Liabilities: Ameren Missouri Derivative liabilities – commodity contracts: Fuel oils $ 1 $ — $ — $ 1 $ — $ — $ — $ — Natural gas — 2 1 3 — 2 1 3 Power 98 — 27 125 45 — 28 73 Uranium — — — — — — 1 1 Total Ameren Missouri $ 99 $ 2 $ 28 $ 129 $ 45 $ 2 $ 30 $ 77 Ameren Illinois Derivative liabilities – commodity contracts: Natural gas $ — $ 6 $ 6 $ 12 $ — $ 5 $ 3 $ 8 Power — — 36 36 — — 117 117 Total Ameren Illinois $ — $ 6 $ 42 $ 48 $ — $ 5 $ 120 $ 125 Ameren Derivative liabilities – commodity contracts (b) $ 99 $ 8 $ 70 $ 177 $ 45 $ 7 $ 150 $ 202 (a) Balance exclude s $9 million and $7 million of cash and cash equivalents, receivables, payables, and accrued income, net, for September 30, 2022, and December 31, 2021, respectively. (b) See the Ameren Missouri and Ameren Illinois sections of the table for a breakout of the fair value of Ameren’s derivative assets and liabilities by type of commodity. (c) See the Ameren Missouri section of the table for a breakout of the fair value of Ameren’s nuclear decommissioning trust fund by investment type. Level 3 fuel oils, natural gas, and uranium derivative contract assets and liabilities measured at fair value on a recurring basis were immaterial for all periods presented. The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and nine months ended September 30, 2022 and 2021: 2022 2021 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren For the three months ended September 30: Beginning balance at July 1 $ (36) $ (44) $ (80) $ (5) $ (166) $ (171) Realized and unrealized gains/(losses) included in regulatory assets/liabilities (10) 30 20 (16) 19 3 Settlements 38 (6) 32 (2) 3 1 Ending balance at September 30 $ (8) $ (20) $ (28) $ (23) $ (144) $ (167) Change in unrealized gains/(losses) related to assets/liabilities held at September 30 $ (3) $ 28 $ 25 $ (17) $ 19 $ 2 For the nine months ended September 30: Beginning balance at January 1 $ (15) $ (117) $ (132) $ 2 $ (198) $ (196) Realized and unrealized gains/(losses) included in regulatory assets/liabilities (56) 105 49 (22) 43 21 Settlements 63 (8) 55 (3) 11 8 Ending balance at September 30 $ (8) $ (20) $ (28) $ (23) $ (144) $ (167) Change in unrealized gains/(losses) related to assets/liabilities held at September 30 $ (39) $ 100 $ 61 $ (21) $ 42 $ 21 All gains or losses related to our Level 3 derivative commodity contracts are expected to be recovered or returned through customer rates; therefore, there is no impact to either net income or other comprehensive income resulting from changes in the fair value of these instruments. The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of September 30, 2022, and December 31, 2021: Fair Value Weighted Average (b) Commodity Assets Liabilities Valuation Technique(s) Unobservable Input (a) Range 2022 Power (c) $ 35 $ (63) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 42 – 118 60 Nodal basis ($/MWh) (15) – 2 (5) Trend rate (%) 0 – 1 0 2021 Power (d) $ 13 $ (145) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 32 – 55 40 Nodal basis ($/MWh) (14) – 0 (2) Trend rate (%) (e) 0 (a) Generally, significant increases (decreases) in these inputs in isolation would result in a significantly higher (lower) fair value measurement. (b) Unobservable inputs were weighted by relative fair value. (c) Valuations through 2031 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2031 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials. (d) Valuations through 2029 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2029 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials. (e) No meaningful range around weighted average. The following table sets forth the carrying amount and, by level within the fair value hierarchy, the fair value of financial assets and liabilities disclosed, but not recorded, at fair value as of September 30, 2022, and December 31, 2021: Carrying Fair Value Level 1 Level 2 Level 3 Total September 30, 2022 Ameren: Cash, cash equivalents, and restricted cash $ 180 $ 180 $ — $ — $ 180 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 1,221 — 1,221 — 1,221 Long-term debt (including current portion) (a) 13,732 (b) — 11,493 446 (c) 11,939 Ameren Missouri: Cash, cash equivalents, and restricted cash $ 7 $ 7 $ — $ — $ 7 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 178 — 178 — 178 Long-term debt (including current portion) (a) 6,140 (b) — 5,352 — 5,352 Ameren Illinois: Cash, cash equivalents, and restricted cash $ 166 $ 166 $ — $ — $ 166 Short-term debt 353 — 353 — 353 Long-term debt (including current portion) 4,489 (b) — 3,868 — 3,868 December 31, 2021 Ameren: Cash, cash equivalents, and restricted cash $ 155 $ 155 $ — $ — $ 155 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 545 — 545 — 545 Long-term debt (including current portion) (a) 13,067 (b) — 13,930 591 (c) 14,521 Ameren Missouri: Cash, cash equivalents, and restricted cash $ 8 $ 8 $ — $ — $ 8 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 165 — 165 — 165 Long-term debt (including current portion) (a) 5,619 (b) — 6,321 — 6,321 Ameren Illinois: Cash, cash equivalents, and restricted cash $ 133 $ 133 $ — $ — $ 133 Short-term debt 103 — 103 — 103 Long-term debt (including current portion) 4,392 (b) — 4,971 — 4,971 (a) Ameren and Ameren Missouri have investments in industrial development revenue bonds, classified as held-to-maturity and recorded in “Other Assets,” that are equal to the finance obligations for the Peno Creek and Audrain CT energy centers. As of September 30, 2022, and December 31, 2021, the carrying amount of both the investments in industrial development revenue bonds and the finance obligations approximated fair value. (b) Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $99 million, $42 million, and $41 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of September 30, 2022. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $94 million, $38 million, and $39 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2021. (c) The Level 3 fair value amount consists of ATXI’s senior unsecured notes. |
Related Party Transactions
Related Party Transactions | 9 Months Ended |
Sep. 30, 2022 | |
Related Party Transactions [Abstract] | |
RELATED PARTY TRANSACTIONS | RELATED-PARTY TRANSACTIONS In the ordinary course of business, Ameren Missouri and Ameren Illinois have engaged in, and may in the future engage in, affiliate transactions. These transactions primarily consist of natural gas and power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between Ameren’s subsidiaries are reported as affiliate transactions on their individual financial statements, but those transactions are eliminated in consolidation for Ameren’s consolidated financial statements. For a discussion of material related-party agreements and money pool arrangements, see Note 13 – Related-party Transactions and Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of the Form 10-K. Support Services Agreements Ameren Missouri and Ameren Illinois had long-term receivables included in “Other assets” from Ameren Services of $80 million and $83 million, respectively, as of September 30, 2022, and $77 million and $80 million, respectively, as of December 31, 2021, related to Ameren Services’ allocated portion of Ameren’s pension and postretirement benefit plans. Tax Allocation Agreement See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for a discussion of the tax allocation agreement. The following table presents the affiliate balances related to income taxes for Ameren Missouri and Ameren Illinois as of September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Income taxes payable to parent (a) $ — $ 72 $ — $ 8 Income taxes receivable from parent (b) 12 — 27 18 (a) Included in “Accounts payable – affiliates” on the balance sheet. (b) Included in “Accounts receivable – affiliates” on the balance sheet. Effects of Related-party Transactions on the Statement of Income The following table presents the impact on Ameren Missouri and Ameren Illinois of related-party transactions for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months Agreement Income Statement Ameren Ameren Ameren Ameren Ameren Missouri power supply Operating Revenues 2022 $ 2 $ (a) $ 7 $ (a) agreements with Ameren Illinois 2021 5 (a) 10 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2022 $ 6 $ (b) $ 18 $ (b) rent and facility services 2021 6 (b) 20 (b) Ameren Missouri and Ameren Illinois miscellaneous Operating Revenues 2022 $ (b) $ (b) $ (b) $ 1 services 2021 (b) 3 (b) 5 Total Operating Revenues 2022 $ 8 $ (b) $ 25 $ 1 2021 11 3 30 5 Ameren Illinois power supply Purchased Power 2022 $ (a) $ 2 $ (a) $ 7 agreements with Ameren Missouri 2021 (a) 5 (a) 10 Ameren Missouri and Ameren Illinois Purchased Power 2022 $ 1 $ (b) $ 1 $ (b) transmission services from ATXI 2021 1 (b) 3 1 Total Purchased Power 2022 $ 1 $ 2 $ 1 $ 7 2021 1 5 3 11 Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2022 $ (b) $ 1 $ (b) $ 2 rent and facility services 2021 (b) 1 (b) 3 Ameren Services support services Other Operations and Maintenance 2022 $ 38 $ 36 $ 109 $ 103 agreement 2021 41 37 110 101 Total Other Operations and 2022 $ 38 $ 37 $ 109 $ 105 Maintenance 2021 41 38 110 104 Money pool borrowings (advances) (Interest Charges)/Other Income, Net 2022 $ (b) $ (b) $ (b) $ (b) 2021 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies
Commitments And Contingencies | 9 Months Ended |
Sep. 30, 2022 | |
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 the 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 9 – Callaway Energy Center, Note 13 – Related-party Transactions, and Note 14 – Commitments and Contingencies 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, and Note 10 – Callaway Energy Center of this report. Environmental Matters Our electric generation, transmission, and distribution and natural gas distribution and storage operations must comply with a variety of statutes and regulations relating to the protection of the environment and human health and safety, including permitting programs implemented via federal, state, and local authorities. Such environmental laws address air emissions; discharges to water bodies; the storage, handling and disposal of hazardous substances and waste materials; siting and land use requirements; and potential ecological impacts. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing, or modified facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures. We employ dedicated personnel knowledgeable in environmental matters to oversee our business activities’ compliance with regulatory requirements. Environmental regulations have a significant impact on the electric utility industry and compliance with these regulations could be costly for Ameren Missouri, which operates coal-fired power plants. Regulations under the Clean Air Act that apply to the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO 2 , particulate matter, NOx, mercury, toxic metals and acid gases, and CO 2 emissions from new power plants. Regulations implementing the Clean Water Act govern both intake and discharges of water, as well as evaluation of the ecological and biological impact of our operations and could require modifications to water intake structures or more stringent limitations on wastewater discharges. Depending upon the scope of modifications ultimately required by state regulators, capital expenditures associated with these modifications could be significant. The management and disposal of coal ash is regulated under the Resource Conservation and Recovery Act and the CCR Rule, which require the closure of certain surface impoundments at Ameren Missouri’s coal-fired energy centers. The individual or combined effects of compliance with existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of operations at some of Ameren Missouri’s energy centers. Ameren and Ameren Missouri expect that such compliance costs would be recoverable through rates, subject to MoPSC prudence review, but the timing of costs and their recovery could be subject to regulatory lag. Additionally, Ameren Missouri’s wind generation facilities may be subject to operating restrictions to limit the impact on protected species. Nighttime operating restrictions may be required during the critical biological season, which typically occurs from April through October. Seasonal nighttime curtailment began at the High Prairie Renewable Energy Center at the end of March 2022. Ameren Missouri expects to resume nighttime operations in November 2022, but the extent and duration of future seasonal nighttime curtailment is unknown as assessment of mitigation technologies is ongoing. Ameren Missouri does not anticipate these operating curtailments to result in significant impacts on its results of operations, financial position, or liquidity. Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $125 million to $175 million from 2022 through 2026 in order to comply with existing environmental regulations. Additional environmental controls beyond 2026 could be required. This estimate of capital expenditures includes ash pond closure and corrective action measures required by the CCR Rule and potential modifications to cooling water intake structures at existing power plants under Clean Water Act rules, all of which are discussed below. In addition to planned retirements of fossil fuel-fired energy centers as set forth in the 2022 Change to the 2020 IRP filed with the MoPSC in June 2022 and as noted in the NSR and Clean Air Act litigation and Illinois emissions standards discussed below, Ameren Missouri’s current plan for compliance with existing air emission regulations includes burning low-sulfur coal and installing new or optimizing existing air pollution control equipment. The actual amount of capital expenditures required to comply with existing environmental regulations may vary substantially from the above estimates because of uncertainty as to future permitting requirements made by state regulators and the EPA, potential revisions to regulatory obligations, and the cost of potential compliance strategies, among other things. The following sections describe the more significant environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. The EPA has initiated an administrative review of several regulations and proposed amendments to regulations and guidelines, including the CSAPR, which could ultimately result in the revision of all or part of such rules. Clean Air Act Federal and state laws, including CSAPR, regulate emissions of SO 2 and NO x through the reduction of emissions at their source and the use and retirement of emission allowances. CSAPR is implemented through a series of phases, and the second phase became effective in 2017. In April 2022, the EPA proposed plans for additional emission reductions from power plants in Missouri, Illinois, and other states through revisions to the CSAPR; and additional emission reduction requirements may apply in subsequent years. The EPA expects to issue a final rule in March 2023. Ameren Missouri complies with current CSAPR requirements by minimizing emissions through the use of low-sulfur coal, operation of two scrubbers at its Sioux Energy Center, and optimization of other existing air pollution control equipment. Ameren Missouri could incur additional costs to lower its emissions at one or more of its energy centers to comply with additional CSAPR requirements in future years. These additional costs for compliance are expected to be recovered from customers through the FAC or higher base rates. CO 2 Emissions Standards In June 2022, the United States Supreme Court issued its decision in West Virginia v. EPA . The decision clarifies that there are limits on how the EPA may regulate greenhouse gases absent further direction from the United States Congress. The court concluded that emission caps that would cause generation shifting from fossil-fuel-fired power plants to renewable energy facilities would require specific congressional authorization and that such authorization had not been given under the Clean Air Act. The decision by the United States Supreme Court may affect the EPA’s development of any new regulations to address CO 2 emissions from coal- and natural gas-fired power plants; however, at this time, Ameren Missouri cannot predict the impact of any such regulations or the decision by the United States Supreme Court on the results of operations, financial position, and liquidity of Ameren or Ameren Missouri. NSR and Clean Air Act Litigation In January 2011, the United States 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 alleging that projects performed in 2007 and 2010 at the coal-fired Rush Island Energy Center violated provisions of the Clean Air Act and Missouri law. In January 2017, the district court issued a liability ruling against Ameren Missouri and, in September 2019, entered a remedy order that required Ameren Missouri to install a flue gas desulfurization system at the Rush Island Energy Center and a dry sorbent injection system at the Labadie Energy Center. Following an appeal from Ameren Missouri in August 2021, the United States Court of Appeals for the Eighth Circuit affirmed the liability ruling and the district court’s remedy order as it related to the installation of a flue gas desulfurization system at the Rush Island Energy Center, but reversed the order as it related to the installation of a dry sorbent injection system at the Labadie Energy Center. In November 2021, the court of appeals issued an order denying requests for consideration previously sought by both Ameren Missouri and the United States Department of Justice. Based on its assessment of available legal, operational, and regulatory alternatives, Ameren Missouri filed a motion in December 2021, with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The March 31, 2024 compliance date contained in the district court’s September 2019 remedy order remains in effect unless extended by the district court. In July 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISO, and Ameren Missouri has started design and procurement activities necessary to complete the upgrades and expects to complete the upgrades by late 2025. In October 2022, the FERC approved a system support resource agreement, which became effective retroactively as of September 1, 2022. The agreement details the manner of continued operation for a system support resource that results in operating during peak demand times and emergencies. The system support resource designation and the related agreement are subject to annual renewal and revision. In September 2022, the Rush Island Energy Center began operating consistent with the system support resource agreement. In addition, in October 2022, the FERC established hearing and settlement procedures in response to an August 2022 request from Ameren Missouri for recovery of non-energy costs under the related MISO tariff. The FERC is under no deadline to issue an order related to this proceeding. Revenues and costs under the MISO tariff are expected to be included in the FAC. The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISO determination of the Rush Island Energy Center as a system support resource or the FERC’s approval. The district court is under no deadline to issue a ruling modifying the remedy order. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review the planned accelerated retirement of the Rush Island Energy Center. See Note 2 – Rate and Regulatory Matters for additional information. In connection with the planned accelerated retirement of the Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute. As such, Ameren Missouri did not request a change in the depreciation rates related to the Rush Island Energy Center in the electric regulatory rate review filed in August 2022. See Note 2 – Rate and Regulatory Matters for additional information on the August 2022 electric regulatory rate review. As of September 30, 2022, the Rush Island Energy Center had a net plant balance of approximately $0.6 billion included in plant to be abandoned, net, within “Property, Plant, and Equipment, Net” and a rate base of approximately $0.5 billion. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for additional information regarding plant to be abandoned, net. In addition, Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the planned acceleration of the retirement of the Rush Island Energy Center from 2039, the retirement year for the facility as reflected in the 2020 IRP and reflected in depreciation rates approved by the December 2021 MoPSC electric rate order. Ameren Missouri is unable to predict the ultimate resolution of this matter; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. Clean Water Act The EPA’s regulations implementing Section 316(b) of the Clean Water Act require power plant operators to evaluate cooling water intake structures and identify measures for reducing the number of aquatic organisms impinged on a power plant’s cooling water intake screens or entrained through the plant’s cooling water system. All of Ameren Missouri’s coal-fired and nuclear energy centers are subject to the cooling water intake structures rule. Requirements of the rule are implemented by state regulators through the permit renewal process of each power plant’s water discharge permit. Permits for Ameren Missouri’s coal-fired and nuclear energy centers have been issued or are in the process of renewal. In 2015, the EPA issued a rule to revise the effluent limitation guidelines applicable to steam electric generating units. These guidelines established national standards for water discharges, prohibit effluent discharges of certain waste streams, and impose more stringent limitations on certain water discharges from power plants by 2025. To meet the requirements of the guidelines, Ameren Missouri installed dry ash handling systems and in 2020 completed construction of wastewater treatment facilities at three of its four coal-fired energy centers. The Meramec Energy Center will be retired by the end of 2022 and, as a result, does not require new wastewater and dry ash handling systems. CCR Management The EPA’s CCR Rule establishes requirements for the management and disposal of CCR from coal-fired power plants and will result in the closure of certain surface impoundments at Ameren Missouri’s energy centers. Ameren Missouri completed the closure of all surface impoundments at its Labadie and Rush Island energy centers in 2021, and has made significant progress by closing several surface impoundments at its Sioux and Meramec energy centers. Ameren Missouri plans to complete the closures of the remaining surface impoundments as required by the CCR Rule in 2024. In January 2022, Ameren Missouri received notices of a proposed determination by the EPA preliminarily denying Ameren Missouri’s requests to extend the timeline for operating certain surface impoundments located at the Sioux and Meramec energy centers. Pursuant to the terms of the proposed determinations, compliance with the CCR Rule’s requirements for closure of the surface impoundments would be required 135 days after the EPA issues a final determination. In February 2022, Ameren Missouri filed comments with the EPA requesting additional time to construct a CCR Rule-compliant impoundment at the Sioux Energy Center and complete the closure of the surface impoundments at the Meramec Energy Center. The EPA is under no deadline to issue a final determination. Continued use of surface impoundments at the Sioux or Meramec energy centers is necessary to support ongoing operations. Ameren Missouri will retire the Meramec Energy Center by the end of 2022, and construction of a CCR Rule-compliant surface impoundment at the Sioux Energy Center is expected to be completed by the end of 2022 to allow for continued operations. Ameren Missouri does not expect that this matter will have a material adverse effect on its results of operations, financial position, or liquidity. Ameren and Ameren Missouri have AROs of $49 million recorded on their respective balance sheets as of September 30, 2022, associated with CCR storage facilities. Ameren Missouri estimates it will need to make capital expenditures of $60 million to $80 million from 2022 through 2026 to implement its CCR management compliance plan, which includes installation of groundwater monitoring equipment and groundwater treatment facilities. Remediation The Ameren Companies are involved in a number of remediation actions to clean up sites impacted by the use or disposal of materials containing hazardous substances. Federal and state laws can require responsible parties to fund remediation regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site. As of September 30, 2022, Ameren Illinois has remediated the majority of the 44 former MGP sites in Illinois and could substantially conclude remediation efforts at the remaining sites by 2023. The ICC allows Ameren Illinois to recover such remediation and related litigation costs from its electric and natural gas utility customers through environmental cost riders that are subject to annual prudence reviews by the ICC. As of September 30, 2022, Ameren Illinois estimated the remaining obligation related to these former MGP sites at $71 million to $145 million. Ameren and Ameren Illinois recorded a liability of $71 million to represent the estimated minimum obligation for these sites, as no other amount within the range was a better estimate. About half of the remaining liability recorded relates to remediation activities that are expected to be completed after 2023. The scope of the remediation activities at these former MGP sites may increase as remediation efforts continue. Considerable uncertainty remains in these estimates because many site-specific factors can influence the actual costs, including unanticipated underground structures, the degree to which groundwater is encountered, regulatory changes, local ordinances, and site accessibility. The actual costs and timing of completion may vary substantially from these estimates. 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 historical practices will result in future environmental commitments or will affect our results of operations, financial position, or liquidity. Illinois Emission Standards The IETL established emission standards that became effective in September 2021. Ameren Missouri’s natural gas-fired energy centers in Illinois are subject to limits on emissions, including CO 2 and NOx, equal to their unit-specific average emissions from 2018 through 2020, for any rolling twelve-month period beginning October 1, 2021, through 2029. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure of the Venice Energy Center by 2029. The reductions could also limit the operations of Ameren Missouri’s other four natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to conditions in the IETL, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service as necessary. Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the updated scheduled retirement dates of the natural gas-fired energy centers located in the state of Illinois. |
Callaway Energy Center
Callaway Energy Center | 9 Months Ended |
Sep. 30, 2022 | |
Nuclear Waste Matters [Abstract] | |
CALLAWAY ENERGY CENTER | CALLAWAY ENERGY CENTER See Note 9 – Callaway Energy Center under Part II, Item 8, of the Form 10-K for information regarding spent nuclear fuel recovery, recovery of decommissioning costs, and the nuclear decommissioning trust fund. 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. 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. An updated cost study and funding analysis was filed with the MoPSC in November 2020 and reflected within the ARO. In February 2021, the MoPSC approved no change in electric rates for decommissioning costs based on Ameren Missouri’s updated cost study funding analysis. See Note 13 – Supplemental Information for more information on Ameren Missouri’s AROs. Maintenance Outage See Note 9 – Callaway Energy Center under Part II, Item 8, of the Form 10-K for information regarding a maintenance outage from a non-nuclear operating issue related to the Callaway Energy Center’s generator in late December 2020 and subsequent return to service on August 4, 2021, along with the related insurance claims. In April 2022, Ameren Missouri received $22 million from NEIL related to lost sales insurance claims. Insurance The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at September 30, 2022: Type and Source of Coverage Most Recent Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers January 1, 2022 $ 450 $ — Pool participation (a) 13,210 (a) 138 (b) $ 13,660 (c) $ 138 Property damage: NEIL and EMANI April 1, 2022 $ 3,200 (d) $ 26 (e) Accidental outage: NEIL April 1, 2022 $ 490 (f) $ 7 (e) (a) Provided through mandatory participation in an industrywide retrospective premium assessment program. The maximum coverage available is dependent on the number of United States commercial reactors participating in the program. (b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $450 million in the event of an incident at any licensed United States commercial reactor, payable at $21 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. This limit is subject to change to account for the effects of inflation and changes in the number of licensed power reactors. (d) NEIL provides $2.7 billion in property damage, stabilization, decontamination, and premature decommissioning insurance for radiation events and $2.3 billion in property damage insurance for nonradiation events. EMANI provides $490 million in property damage insurance for both radiation and nonradiation events. (e) All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. (f) Accidental outage insurance provides for lost sales in the event of a prolonged accidental outage. Weekly indemnity up to $4.5 million for 52 weeks, which commences after the first 12 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 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 November 2018. 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 insured by NEIL are subject to industrywide aggregates, such that terrorist acts against one or more commercial nuclear power plants within a stated time period would be treated as a single event, and the owners of the nuclear power plants would share the limit of liability. NEIL policies have an aggregate limit of $3.2 billion within a 12-month period for radiation events, or $1.8 billion for events not involving radiation contamination, resulting from terrorist attacks. The EMANI policies are not subject to industrywide aggregates in the event of terrorist attacks on nuclear facilities. If losses from a nuclear incident at the Callaway Energy Center exceed the limits of, or are not covered by insurance, or if coverage is unavailable, Ameren Missouri is at risk for any uninsured losses. If a serious nuclear incident were to occur, it could have a material adverse effect on Ameren’s and Ameren Missouri’s results of operations, financial position, or liquidity. |
Retirement Benefits
Retirement Benefits | 9 Months Ended |
Sep. 30, 2022 | |
Retirement Benefits [Abstract] | |
RETIREMENT BENEFITS | RETIREMENT BENEFITS The following table presents the components of the net periodic benefit cost (income) incurred for Ameren’s pension and postretirement benefit plans for the three and nine months ended September 30, 2022 and 2021: Pension Benefits Postretirement Benefits Three Months Nine Months Three Months Nine Months 2022 2021 2022 2021 2022 2021 2022 2021 Service cost (a) $ 31 $ 33 $ 95 $ 100 $ 5 $ 5 $ 15 $ 17 Non-service cost components: Interest cost 42 38 123 114 8 9 25 25 Expected return on plan assets (80) (74) (240) (223) (21) (20) (64) (60) Amortization of: Prior service benefit — — — — (1) (1) (3) (3) Actuarial loss (gain) 7 18 19 55 (5) (1) (14) (4) Total non-service cost components (b) $ (31) $ (18) $ (98) $ (54) $ (19) $ (13) $ (56) $ (42) Net periodic benefit cost (income) (c) $ — $ 15 $ (3) $ 46 $ (14) $ (8) $ (41) $ (25) (a) Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income. (b) Non-service cost components are reflected in “Other Income, Net” on Ameren’s statement of income. See Note 5 – Other Income, Net, for additional information. (c) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. Ameren Missouri and Ameren Illinois are responsible for their respective share of Ameren’s pension and other postretirement costs. The following table presents the respective share of net periodic pension and other postretirement benefit costs (income) incurred for the three and nine months ended September 30, 2022 and 2021: Pension Benefits Postretirement Benefits Three Months Nine Months Three Months Nine Months 2022 2021 2022 2021 2022 2021 2022 2021 Ameren Missouri (a) $ — $ 7 $ (2) $ 22 $ (3) $ (1) $ (10) $ (3) Ameren Illinois 1 8 2 25 (11) (8) (31) (23) Other (1) — (3) (1) — 1 — 1 Ameren (a) $ — $ 15 $ (3) $ 46 $ (14) $ (8) $ (41) $ (25) (a) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. |
Income Taxes
Income Taxes | 9 Months Ended |
Sep. 30, 2022 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | INCOME TAXES The following table presents a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the three and nine months ended September 30, 2022 and 2021: Ameren Ameren Missouri Ameren Illinois 2022 2021 2022 2021 2022 2021 Three Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of deferred investment tax credit — (1) (1) (1) — — Amortization of excess deferred taxes (a) (8) (8) (15) (17) (2) (2) Depreciation differences — — — — — (1) Renewable and other tax credits (b) (4) (2) (10) (8) — — State tax 4 4 3 4 7 7 Stock-based compensation 1 — — — — — Cash surrender value of COLI 1 — — — — — Effective income tax rate 15 % 14 % (2) % (1) % 26 % 25 % Nine Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of deferred investment tax credit — — (1) — — — Amortization of excess deferred taxes (a) (8) (9) (15) (17) (2) (3) Renewable and other tax credits (b) (4) (3) (10) (8) — — State tax 5 5 3 3 7 7 Stock-based compensation — (1) — — — — Effective income tax rate 14 % 13 % (2) % (1) % 26 % 25 % (a) Reflects the amortization of amounts resulting from the revaluation of deferred income taxes subject to regulatory ratemaking, which are being refunded to customers. Deferred income taxes are revalued when federal or state income tax rates change, and the offset to the revaluation of deferred income taxes subject to regulatory ratemaking is recorded to a regulatory asset or liability. (b) Includes credits associated with the High Prairie and Atchison renewable energy centers. Ameren Missouri placed the High Prairie Renewable Energy Center in service in December 2020. Additionally, Ameren Missouri placed in service the wind turbines at its Atchison Renewable Energy Center throughout the first half of 2021. The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM. IRA The IRA was enacted in August 2022, and includes various income tax provisions, among other things. The law extends federal production and investment tax credits for projects beginning construction through 2024 and allows for a 10% adder to the production and investment tax credits for siting projects at existing energy communities as defined in the law, which includes sites previously used for coal-fired generation. The law also creates clean energy tax credits for projects placed in service after 2024. The clean energy tax credits will apply to renewable energy production and investments, along with certain nuclear energy production, and will be phased out beginning in 2033, at the earliest. The phase-out is triggered when greenhouse gas emissions from the electric generation industry are reduced by at least 75% from the annual 2022 emission rate or at the beginning of 2033, whichever is later. The law allows for transferability to an unrelated party for cash of up to 100% of certain tax credits generated after 2022. In addition, the new law imposes a 15% minimum tax on adjusted financial statement income, as defined in the law, for corporations whose average annual adjusted financial statement income exceeds $1 billion for three consecutive preceding tax years effective for tax years beginning after December 31, 2022. Once a corporation exceeds this three-year average annual adjusted financial statement income threshold, it will be subject to the minimum tax for all future tax years. Ameren is currently evaluating the IRA and does not expect to be subject to the minimum tax imposed by the IRA in 2023. Implementation of the IRA provisions is subject to additional regulations, interpretations, amendments, or technical corrections that may be issued by the IRS or United States Department of Treasury. |
Supplemental Information
Supplemental Information | 9 Months Ended |
Sep. 30, 2022 | |
Supplemental Information [Abstract] | |
Supplemental Information | SUPPLEMENTAL INFORMATION Cash, Cash Equivalents, and Restricted Cash The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets and the statements of cash flows at September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Ameren Ameren Ameren Ameren Ameren Ameren “Cash and cash equivalents” $ 7 $ — $ — $ 8 $ — $ — Restricted cash included in “Other current assets” 7 3 4 16 4 6 Restricted cash included in “Other assets” 162 — 162 127 — 127 Restricted cash included in “Nuclear decommissioning trust fund” 4 4 — 4 4 — Total cash, cash equivalents, and restricted cash $ 180 $ 7 $ 166 $ 155 $ 8 $ 133 Restricted cash included in “Other current assets” primarily represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees. Restricted cash included in “Other assets” on Ameren’s and Ameren Illinois’ balance sheets primarily represents amounts collected under a cost recovery rider restricted for use in the procurement of renewable energy credits and amounts in a trust fund restricted for the use of funding certain asbestos-related claims. Accounts Receivable “Accounts receivable – trade” on Ameren’s and Ameren Illinois’ balance sheets include certain receivables purchased at a discount from alternative retail electric suppliers that elect to participate in the utility consolidated billing program. At September 30, 2022, and December 31, 2021, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of $32 million and $27 million, respectively. The following table provides a reconciliation of the beginning and ending amount of the allowance for doubtful accounts for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren: Beginning of period $ 30 $ 42 $ 29 $ 50 Bad debt expense 15 7 26 8 Net write-offs (14) (13) (24) (22) End of period $ 31 $ 36 $ 31 $ 36 Ameren Missouri: Beginning of period $ 12 $ 16 $ 13 $ 16 Bad debt expense 3 2 6 5 Net write-offs (3) (4) (7) (7) End of period $ 12 $ 14 $ 12 $ 14 Ameren Illinois: (a) Beginning of period $ 18 $ 26 $ 16 $ 34 Bad debt expense 12 5 20 3 (b) Net write-offs (11) (9) (17) (15) End of period $ 19 $ 22 $ 19 $ 22 (a) Ameren Illinois has rate-adjustment mechanisms that allow it to recover the difference between its actual net bad debt write-offs under GAAP, including those associated with receivables purchased from alternative retail electric suppliers, and the amount of net bad debt write-offs included in its base rates. (b) In the nine months ended September 30, 2021, Ameren Illinois’ bad debt expense was reduced as a result of state funding received for customer bill assistance. As of September 30, 2022, accounts receivable balances that were 30 days or greater past due or that were a part of a deferred payment arrangement represented 17%, 12%, and 21%, or $117 million, $39 million, and $78 million, of Ameren’s, Ameren Missouri’s, and Ameren Illinois’ customer trade receivables before allowance for doubtful accounts, respectively. In comparison, as of September 30, 2021, these percentages were 18%, 12%, and 25%, or $97 million, $33 million, and $64 million, for Ameren, Ameren Missouri, and Ameren Illinois, respectively. Supplemental Cash Flow Information Capital expenditures for the nine months ended September 30, 2021, at Ameren and Ameren Missouri included wind generation expenditures of $515 million. The following table provides noncash financing and investing activity excluded from the statements of cash flows for the nine months ended September 30, 2022 and 2021: September 30, 2022 September 30, 2021 Ameren Ameren Ameren Ameren Ameren Ameren Investing Accrued capital expenditures $ 367 $ 187 $ 180 $ 396 $ 209 $ 182 Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund (262) (262) — 85 85 — Financing Issuance of common stock for stock-based compensation $ 31 $ — $ — $ 33 $ — $ — Issuance of common stock under the DRPlus 8 — — — — — Asset Retirement Obligations The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the nine months ended September 30, 2022: Ameren Ameren Ameren Balance at December 31, 2021 $ 760 (a) $ 4 (b) $ 764 (a) Liabilities incurred 1 — 1 Liabilities settled (3) — (3) Accretion 23 (c) — 23 (c) Change in estimates (7) — (7) Balance at September 30, 2022 $ 774 (a) $ 4 (b) $ 778 (a) (a) Balance included $7 million in “Other current liabilities” on the balance sheet as of both September 30, 2022, and December 31, 2021. (b) Included in “Other deferred credits and liabilities” on the balance sheet. (c) Accretion expense attributable to Ameren Missouri was recorded as a decrease to regulatory liabilities. Stock-based Compensation Ameren’s long-term incentive plan available for eligible employees, the 2014 Omnibus Incentive Compensation Plan (2014 Plan), was replaced prospectively for new grants only by the 2022 Omnibus Incentive Compensation Plan (2022 Plan) effective May 12, 2022. The 2022 Plan provides for a maximum of 8.8 million common shares to be available for grant to eligible employees and directors, and retains many of the features of the 2014 Plan. The 2022 Plan permits the grant of restricted stock, restricted stock units, stock options (incentive stock options and nonqualified stock options), stock appreciation rights, performance awards, cash-based awards and other stock-based awards. In the first quarter of 2022 under the 2014 Plan, Ameren granted 267,849 performance share units with a grant date fair value of $25 million and 122,882 restricted share units with a grant date fair value of $11 million. Awards vest approximately 3 years after the grant date or on a pro-rata basis upon death or eligible retirement. The performance share units vest based on the achievement of certain specified market performance measures (229,566 performance share units) or clean energy transition targets (38,283 performance share units). The exact number of shares issued pursuant to a performance share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the performance goals. For the nine months ended September 30, 2022 and 2021, excess tax benefits associated with the settlement of stock-based compensation awards reduced income tax expense by $5 million in both periods. Deferred Compensation At September 30, 2022, and December 31, 2021, the present value of benefits to be paid for deferred compensation obligations was $88 million and $91 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. Operating Revenues As of September 30, 2022 and 2021, our remaining performance obligations for contracts with a term greater than one year were immaterial. The Ameren Companies elected not to disclose the aggregate amount of the transaction price allocated to the performance obligations that are unsatisfied as of the end of the reporting period for contracts with an initial expected term of one year or less. See Note 14 – Segment Information for disaggregated revenue information. Excise Taxes Ameren Missouri and Ameren Illinois collect from their customers excise taxes, including municipal and state excise taxes and gross receipts taxes that are levied on the sale or distribution of natural gas and electricity. The following table presents the excise taxes recorded on a gross basis in “Operating Revenues – Electric,” “Operating Revenues – Natural gas” and “Operating Expenses – Taxes other than income taxes” on the statements of income for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren Missouri $ 55 $ 54 $ 128 $ 120 Ameren Illinois 28 27 101 93 Ameren $ 83 $ 81 $ 229 $ 213 Earnings per Share The following table reconciles the basic weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Weighted-average Common Shares Outstanding – Basic 258.4 257.3 258.2 255.9 Assumed settlement of performance share units and restricted stock units 0.9 1.3 1.0 1.3 Dilutive effect of forward sale agreements 0.2 — 0.1 — Weighted-average Common Shares Outstanding – Diluted (a) 259.5 258.6 259.3 257.2 (a) There was an immaterial number of anti-dilutive securities excluded from the earnings per diluted share calculations for the three and nine months ended September 30, 2022 and 2021. |
Segment Information
Segment Information | 9 Months Ended |
Sep. 30, 2022 | |
Segment Reporting [Abstract] | |
SEGMENT INFORMATION | SEGMENT INFORMATION The following tables present revenues, net income attributable to common shareholders, and capital expenditures by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 2022 and 2021. Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount. For additional information about our segments, see Note 16 – Segment Information under Part II, Item 8, of the Form 10-K. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Other Intersegment Eliminations Ameren Three Months 2022: External revenues $ 1,351 $ 672 $ 146 $ 137 $ — $ — $ 2,306 Intersegment revenues 8 — — 32 — (40) — Net income (loss) attributable to Ameren common shareholders 397 51 (4) 78 (a) (70) — 452 Capital expenditures 431 163 114 187 1 3 899 Three Months 2021: External revenues $ 1,118 $ 425 $ 127 $ 141 $ — $ — $ 1,811 Intersegment revenues 11 3 — 19 — (33) — Net income (loss) attributable to Ameren common shareholders 375 36 (8) 73 (a) (51) — 425 Capital expenditures 466 (b) 143 93 154 2 (8) 850 (b) Nine Months 2022: External revenues $ 3,071 $ 1,640 $ 811 $ 389 $ — $ — $ 5,911 Intersegment revenues 25 1 — 76 — (102) — Net income (loss) attributable to Ameren common shareholders 547 151 82 199 (a) (68) — 911 Capital expenditures 1,237 444 232 519 4 1 2,437 Nine Months 2021: External revenues $ 2,612 $ 1,222 $ 642 $ 373 $ — $ — $ 4,849 Intersegment revenues 30 5 — 53 — (88) — Net income (loss) attributable to Ameren common shareholders 533 123 75 175 (a) (41) — 865 Capital expenditures 1,567 (b) 429 202 426 3 (14) 2,613 (b) (a) Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent). (b) Includes $98 million and $515 million at Ameren and Ameren Missouri for wind generation expenditures for the three and nine months ended September 30, 2021, respectively. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2022: External revenues $ 672 $ 146 $ 86 $ — $ 904 Intersegment revenues — — 31 (31) — Net income (loss) available to common shareholder 51 (4) 56 — 103 Capital expenditures 163 114 169 — 446 Three Months 2021: External revenues $ 428 $ 127 $ 90 $ — $ 645 Intersegment revenues — — 18 (18) — Net income (loss) available to common shareholder 36 (8) 51 — 79 Capital expenditures 143 93 144 — 380 Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Nine Months 2022: External revenues $ 1,641 $ 811 $ 245 $ — $ 2,697 Intersegment revenues — — 75 (75) — Net income available to common shareholder 151 82 142 — 375 Capital expenditures 444 232 469 — 1,145 Nine Months 2021: External revenues $ 1,227 $ 642 $ 228 $ — $ 2,097 Intersegment revenues — — 49 (49) — Net income available to common shareholder 123 75 116 — 314 Capital expenditures 429 202 395 — 1,026 The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 2022 and 2021. Economic factors affect the nature, timing, amount, and uncertainty of revenues and cash flows in a similar manner across customer classes. Revenues from alternative revenue programs have a similar distribution among customer classes as revenues from contracts with customers. Other revenues not associated with contracts with customers are presented in the Other customer classification, along with electric transmission and off-system revenues. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2022: Residential $ 564 $ 407 $ — $ — $ — $ 971 Commercial 430 233 — — — 663 Industrial 99 47 — — — 146 Other 245 (15) — 169 (39) 360 Total electric revenues $ 1,338 $ 672 $ — $ 169 $ (39) $ 2,140 Residential $ 11 $ — $ 89 $ — $ — $ 100 Commercial 6 — 25 — — 31 Industrial 1 — 5 — — 6 Other 3 — 27 — (1) 29 Total natural gas revenues $ 21 $ — $ 146 $ — $ (1) $ 166 Total revenues (a) $ 1,359 $ 672 $ 146 $ 169 $ (40) $ 2,306 Three Months 2021: Residential $ 537 $ 258 $ — $ — $ — $ 795 Commercial 412 143 — — — 555 Industrial 98 26 — — — 124 Other 66 1 — 160 (33) 194 Total electric revenues $ 1,113 $ 428 $ — $ 160 $ (33) $ 1,668 Residential $ 9 $ — $ 75 $ — $ — $ 84 Commercial 4 — 23 — — 27 Industrial — — 3 — — 3 Other 3 — 26 — — 29 Total natural gas revenues $ 16 $ — $ 127 $ — $ — $ 143 Total revenues (a) $ 1,129 $ 428 $ 127 $ 160 $ (33) $ 1,811 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Nine Months 2022: Residential $ 1,267 $ 954 $ — $ — $ — $ 2,221 Commercial 968 571 — — — 1,539 Industrial 229 145 — — — 374 Other 502 (29) — 465 (101) 837 Total electric revenues $ 2,966 $ 1,641 $ — $ 465 $ (101) $ 4,971 Residential $ 78 $ — $ 575 $ — $ — $ 653 Commercial 36 — 152 — — 188 Industrial 4 — 33 — — 37 Other 12 — 51 — (1) 62 Total natural gas revenues $ 130 $ — $ 811 $ — $ (1) $ 940 Total revenues (a) $ 3,096 $ 1,641 $ 811 $ 465 $ (102) $ 5,911 Nine Months 2021: Residential $ 1,177 $ 705 $ — $ — $ — $ 1,882 Commercial 899 402 — — — 1,301 Industrial 221 94 — — — 315 Other 246 26 — 426 (88) 610 Total electric revenues $ 2,543 $ 1,227 $ — $ 426 $ (88) $ 4,108 Residential $ 54 $ — $ 438 $ — $ — $ 492 Commercial 23 — 116 — — 139 Industrial 2 — 20 — — 22 Other 20 — 68 — — 88 Total natural gas revenues $ 99 $ — $ 642 $ — $ — $ 741 Total revenues (a) $ 2,642 $ 1,227 $ 642 $ 426 $ (88) $ 4,849 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and nine months ended September 30, 2022 and 2021: Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Ameren Three Months 2022: Revenues from alternative revenue programs $ 14 $ (83) $ (3) $ (11) $ (83) Other revenues not from contracts with customers (45) (a) 2 — — (43) (a) Three Months 2021: Revenues from alternative revenue programs $ 6 $ (97) $ (5) $ 1 $ (95) Other revenues not from contracts with customers 7 (b) 6 — — 13 (b) Nine Months 2022: Revenues from alternative revenue programs $ 8 $ 13 $ (5) $ (14) $ 2 Other revenues not from contracts with customers (81) (a), (b) 5 2 — (74) (a), (b) Nine Months 2021: Revenues from alternative revenue programs $ (9) $ (2) $ — $ 5 $ (6) Other revenues not from contracts with customers 71 (b) 9 2 — 82 (b) (a) Includes net realized losses on derivative power contracts. (b) Includes insurance recoveries related to lost sales associated with the Callaway Energy Center maintenance outage. See Note 9 – Callaway Energy Center under Part II, Item 8, of the Form 10-K for additional information. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2022: Residential $ 407 $ 89 $ — $ — $ 496 Commercial 233 25 — — 258 Industrial 47 5 — — 52 Other (15) 27 117 (31) 98 Total revenues (a) $ 672 $ 146 $ 117 $ (31) $ 904 Three Months 2021: Residential $ 258 $ 75 $ — $ — $ 333 Commercial 143 23 — — 166 Industrial 26 3 — — 29 Other 1 26 108 (18) 117 Total revenues (a) $ 428 $ 127 $ 108 $ (18) $ 645 Nine Months 2022: Residential $ 954 $ 575 $ — $ — $ 1,529 Commercial 571 152 — — 723 Industrial 145 33 — — 178 Other (29) 51 320 (75) 267 Total revenues (a) $ 1,641 $ 811 $ 320 $ (75) $ 2,697 Nine Months 2021: Residential $ 705 $ 438 $ — $ — $ 1,143 Commercial 402 116 — — 518 Industrial 94 20 — — 114 Other 26 68 277 (49) 322 Total revenues (a) $ 1,227 $ 642 $ 277 $ (49) $ 2,097 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments for the three and nine months ended September 30, 2022 and 2021: Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois Three Months 2022: Revenues from alternative revenue programs $ (83) $ (3) $ (10) $ (96) Other revenues not from contracts with customers 2 — — 2 Three Months 2021: Revenues from alternative revenue programs $ (97) $ (5) $ 3 $ (99) Other revenues not from contracts with customers 6 — — 6 Nine Months 2022: Revenues from alternative revenue programs $ 13 $ (5) $ (12) $ (4) Other revenues not from contracts with customers 5 2 — 7 Nine Months 2021: Revenues from alternative revenue programs $ (2) $ — $ 4 $ 2 Other revenues not from contracts with customers 9 2 — 11 |
Summary Of Significant Accoun_2
Summary Of Significant Accounting Policies (Policies) | 9 Months Ended |
Sep. 30, 2022 | |
Accounting Policies [Abstract] | |
Nature of Operations | Ameren, headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. Ameren has other subsidiaries that conduct other activities, such as providing shared services. • Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri. • Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois. • ATXI operates a FERC rate-regulated electric transmission business in the MISO. |
Consolidation | Ameren’s and Ameren Missouri’s financial statements are prepared on a consolidated basis and therefore include the accounts of their majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Missouri’s subsidiaries were created for the ownership of renewable generation projects. Ameren Illinois has no subsidiaries. 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 reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. The results of operations for 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 accompanying notes included in the Form 10-K. |
Consolidation, Variable Interest Entity, Policy | Variable Interest Entities As of September 30, 2022, and December 31, 2021, Ameren had unconsolidated variable interests as a limited partner in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $58 million and $56 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Any earnings or losses related to these investments are included in “Other Income, Net” on Ameren’s consolidated statement of income and comprehensive income. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of September 30, 2022, the maximum exposure to loss related to these variable interests is limited to the investment in these partnerships of $58 million plus associated outstanding funding commitments of $21 million. |
Life Insurance, Corporate Or Bank Owned | COLIAmeren and Ameren Illinois have COLI, which is recorded at the net cash surrender value. The net cash surrender value is the amount that can be realized under the insurance policies at the balance sheet date. |
Derivatives, Policy | We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following: • an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices; • market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; • actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays; and • actual off-system sales revenues that differ from anticipated revenues. 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. All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. 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. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting. |
Deferred Compensation | Deferred Compensation At September 30, 2022, and December 31, 2021, the present value of benefits to be paid for deferred compensation obligations was $88 million and $91 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. |
Revenue from Contract with Customer | Operating Revenues As of September 30, 2022 and 2021, our remaining performance obligations for contracts with a term greater than one year were immaterial. The Ameren Companies elected not to disclose the aggregate amount of the transaction price allocated to the performance obligations that are unsatisfied as of the end of the reporting period for contracts with an initial expected term of one year or less. See Note 14 – Segment Information for disaggregated revenue information. |
Excise Taxes | Excise TaxesAmeren Missouri and Ameren Illinois collect from their customers excise taxes, including municipal and state excise taxes and gross receipts taxes that are levied on the sale or distribution of natural gas and electricity. |
Short-Term Debt and Liquidity (
Short-Term Debt and Liquidity (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Debt Disclosure [Abstract] | |
Schedule of Short-term Debt | The following table presents commercial paper outstanding, net of issuance discounts, as of September 30, 2022, and December 31, 2021. There were no borrowings outstanding under the Credit Agreements as of September 30, 2022, or December 31, 2021. September 30, 2022 December 31, 2021 Ameren (parent) $ 690 $ 277 Ameren Missouri 178 165 Ameren Illinois 353 103 Ameren consolidated $ 1,221 $ 545 The following table summarizes the activity and relevant interest rates for Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper issuances and borrowings under the Credit Agreements in the aggregate for the nine months ended September 30, 2022 and 2021: Ameren Ameren Ameren Ameren 2022 Average daily amount outstanding $ 439 $ 253 $ 99 $ 791 Weighted-average interest rate 1.58 % 1.16 % 1.77 % 1.47 % Peak amount outstanding during period (a) $ 690 $ 539 $ 354 $ 1,222 Peak interest rate 3.55 % 3.55 % 3.60 % 3.60 % 2021 Average daily amount outstanding $ 404 $ 121 $ 140 $ 665 Weighted-average interest rate 0.23 % 0.22 % 0.22 % 0.22 % Peak amount outstanding during period (a) $ 650 $ 546 $ 485 $ 1,134 Peak interest rate 0.33 % 0.25 % 0.25 % 0.33 % (a) The timing of peak outstanding commercial paper issuances and borrowings under the Credit Agreements varies by company. Therefore, the sum of individual company peak amounts may not equal the Ameren consolidated peak for the period. |
Other Income, Net (Tables)
Other Income, Net (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Other Nonoperating Income (Expense) [Abstract] | |
Other Income And Expenses | The following table presents the components of “Other Income, Net” in the Ameren Companies’ statements of income for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren: Allowance for equity funds used during construction $ 12 $ 14 $ 31 $ 30 Interest income on industrial development revenue bonds 6 7 18 19 Non-service cost components of net periodic benefit income (a) 45 34 138 102 Miscellaneous income 5 1 14 7 Earnings (losses) related to equity method investments (3) 2 1 8 Donations (1) (1) (5) (5) Miscellaneous expense (6) (1) (17) (10) Total Other Income, Net $ 58 $ 56 $ 180 $ 151 Ameren Missouri: Allowance for equity funds used during construction $ 7 $ 7 $ 17 $ 17 Interest income on industrial development revenue bonds 6 7 18 19 Non-service cost components of net periodic benefit income (a) 13 13 41 41 Miscellaneous income 2 2 5 3 Donations — — (2) (1) Miscellaneous expense (3) (2) (7) (5) Total Other Income, Net $ 25 $ 27 $ 72 $ 74 Ameren Illinois: Allowance for equity funds used during construction $ 5 $ 7 $ 14 $ 13 Non-service cost components of net periodic benefit income 21 13 63 41 Miscellaneous income 4 — 9 4 Donations (1) (1) (3) (4) Miscellaneous expense (3) — (8) (5) Total Other Income, Net $ 26 $ 19 $ 75 $ 49 (a) For the three and nine months ended September 30, 2022, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $5 million and $16 million, respectively, due to a regulatory tracking mechanism for the difference between the level of such costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. The deferral was $(3) million and $(6) million for both the three and nine months ended September 30, 2021, respectively. See Note 11– Retirement Benefits for additional information. |
Derivative Financial Instrume_2
Derivative Financial Instruments (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
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 September 30, 2022, and December 31, 2021. As of September 30, 2022, these contracts extended through October 2024, October 2027, May 2032 and March 2024 for fuel oils, natural gas, power and uranium, respectively: Quantity (in millions) September 30, 2022 December 31, 2021 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) 19 — 19 30 — 30 Natural gas (in mmbtu) 43 144 187 35 144 179 Power (in MWhs) 2 6 8 6 6 12 Uranium (pounds in thousands) 406 — 406 586 — 586 |
Derivative Instruments Carrying Value | The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Balance Sheet Location Ameren Ameren Ameren Ameren Ameren Ameren Fuel oils Other current assets 12 — 12 8 — 8 Other assets 3 — 3 5 — 5 Natural gas Mark-to-market derivative assets (a) 57 (a) (a) 28 (a) Other current assets 14 — 71 7 — 35 Other assets 13 21 34 5 13 18 Power Mark-to-market derivative assets (a) 11 (a) (a) — (a) Other current assets 28 — 39 23 — 23 Other assets — 5 5 — — — Uranium Other current assets 2 — 2 — — — Other assets 1 — 1 1 — 1 Total assets $ 73 $ 94 $ 167 $ 49 $ 41 $ 90 Fuel oils Other deferred credits and liabilities 1 — 1 — — — Natural gas Mark-to-market derivative liabilities 2 (a) (a) 2 (a) (a) Other current liabilities — 9 11 — 6 8 Other deferred credits and liabilities 1 3 4 1 2 3 Power Mark-to-market derivative liabilities 111 (a) (a) 50 (a) (a) Other current liabilities — — 111 — 9 59 Other deferred credits and liabilities 14 36 50 23 108 131 Uranium Mark-to-market derivative liabilities — (a) (a) 1 (a) (a) Other current liabilities — — — — — 1 Total liabilities $ 129 $ 48 $ 177 $ 77 $ 125 $ 202 (a) Balance sheet line item not applicable to registrant. |
Offsetting 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 September 30, 2022, and December 31, 2021: 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 September 30, 2022 Assets: Ameren Missouri $ 73 $ 18 $ 2 $ 53 Ameren Illinois 94 13 1 80 Ameren $ 167 $ 31 $ 3 $ 133 Liabilities: Ameren Missouri $ 129 $ 18 $ 99 $ 12 Ameren Illinois 48 13 — 35 Ameren $ 177 $ 31 $ 99 $ 47 December 31, 2021 Assets: Ameren Missouri $ 49 $ 15 $ — $ 34 Ameren Illinois 41 4 — 37 Ameren $ 90 $ 19 $ — $ 71 Liabilities: Ameren Missouri $ 77 $ 15 $ 47 $ 15 Ameren Illinois 125 4 — 121 Ameren $ 202 $ 19 $ 47 $ 136 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Current collateral assets” and “Other assets” on the balance sheet for Ameren and Ameren Missouri and “Other current assets” and “Other assets” for Ameren Illinois. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Fair Value Disclosures [Abstract] | |
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 September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Ameren Missouri Derivative assets – commodity contracts: Fuel oils $ 13 $ — $ 2 $ 15 $ 13 $ — $ — $ 13 Natural gas 1 26 — 27 — 12 — 12 Power 9 — 19 28 10 — 13 23 Uranium — — 3 3 — — 1 1 Total derivative assets – commodity contracts $ 23 $ 26 $ 24 $ 73 $ 23 $ 12 $ 14 $ 49 Nuclear decommissioning trust fund: Equity securities: U.S. large capitalization $ 574 $ — $ — $ 574 $ 824 $ — $ — $ 824 Debt securities: U.S. Treasury and agency securities — 148 — 148 — 141 — 141 Corporate bonds — 115 — 115 — 131 — 131 Other — 64 — 64 — 56 — 56 Total nuclear decommissioning trust fund $ 574 $ 327 $ — $ 901 (a) $ 824 $ 328 $ — $ 1,152 (a) Total Ameren Missouri $ 597 $ 353 $ 24 $ 974 $ 847 $ 340 $ 14 $ 1,201 Ameren Illinois Derivative assets – commodity contracts: Natural gas $ 6 $ 65 $ 7 $ 78 $ 1 $ 33 $ 7 $ 41 Power — — 16 16 — — — — Total Ameren Illinois $ 6 $ 65 $ 23 $ 94 $ 1 $ 33 $ 7 $ 41 Ameren Derivative assets – commodity contracts (b) $ 29 $ 91 $ 47 $ 167 $ 24 $ 45 $ 21 $ 90 Nuclear decommissioning trust fund (c) 574 327 — 901 (a) 824 328 — 1,152 (a) Total Ameren $ 603 $ 418 $ 47 $ 1,068 $ 848 $ 373 $ 21 $ 1,242 Liabilities: Ameren Missouri Derivative liabilities – commodity contracts: Fuel oils $ 1 $ — $ — $ 1 $ — $ — $ — $ — Natural gas — 2 1 3 — 2 1 3 Power 98 — 27 125 45 — 28 73 Uranium — — — — — — 1 1 Total Ameren Missouri $ 99 $ 2 $ 28 $ 129 $ 45 $ 2 $ 30 $ 77 Ameren Illinois Derivative liabilities – commodity contracts: Natural gas $ — $ 6 $ 6 $ 12 $ — $ 5 $ 3 $ 8 Power — — 36 36 — — 117 117 Total Ameren Illinois $ — $ 6 $ 42 $ 48 $ — $ 5 $ 120 $ 125 Ameren Derivative liabilities – commodity contracts (b) $ 99 $ 8 $ 70 $ 177 $ 45 $ 7 $ 150 $ 202 (a) Balance exclude s $9 million and $7 million of cash and cash equivalents, receivables, payables, and accrued income, net, for September 30, 2022, and December 31, 2021, respectively. (b) See the Ameren Missouri and Ameren Illinois sections of the table for a breakout of the fair value of Ameren’s derivative assets and liabilities by type of commodity. (c) See the Ameren Missouri section of the table for a breakout of the fair value of Ameren’s nuclear decommissioning trust fund by investment type. |
Schedule Of Changes In The Fair Value Of Financial Assets And Liabilities Classified As Level Three In The Fair Value Hierarchy | The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and nine months ended September 30, 2022 and 2021: 2022 2021 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren For the three months ended September 30: Beginning balance at July 1 $ (36) $ (44) $ (80) $ (5) $ (166) $ (171) Realized and unrealized gains/(losses) included in regulatory assets/liabilities (10) 30 20 (16) 19 3 Settlements 38 (6) 32 (2) 3 1 Ending balance at September 30 $ (8) $ (20) $ (28) $ (23) $ (144) $ (167) Change in unrealized gains/(losses) related to assets/liabilities held at September 30 $ (3) $ 28 $ 25 $ (17) $ 19 $ 2 For the nine months ended September 30: Beginning balance at January 1 $ (15) $ (117) $ (132) $ 2 $ (198) $ (196) Realized and unrealized gains/(losses) included in regulatory assets/liabilities (56) 105 49 (22) 43 21 Settlements 63 (8) 55 (3) 11 8 Ending balance at September 30 $ (8) $ (20) $ (28) $ (23) $ (144) $ (167) Change in unrealized gains/(losses) related to assets/liabilities held at September 30 $ (39) $ 100 $ 61 $ (21) $ 42 $ 21 |
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Valuation Techniques | The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of September 30, 2022, and December 31, 2021: Fair Value Weighted Average (b) Commodity Assets Liabilities Valuation Technique(s) Unobservable Input (a) Range 2022 Power (c) $ 35 $ (63) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 42 – 118 60 Nodal basis ($/MWh) (15) – 2 (5) Trend rate (%) 0 – 1 0 2021 Power (d) $ 13 $ (145) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 32 – 55 40 Nodal basis ($/MWh) (14) – 0 (2) Trend rate (%) (e) 0 (a) Generally, significant increases (decreases) in these inputs in isolation would result in a significantly higher (lower) fair value measurement. (b) Unobservable inputs were weighted by relative fair value. (c) Valuations through 2031 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2031 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials. (d) Valuations through 2029 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2029 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials. (e) No meaningful range around weighted average. |
Schedule of Financial Assets and Liabilities | The following table sets forth the carrying amount and, by level within the fair value hierarchy, the fair value of financial assets and liabilities disclosed, but not recorded, at fair value as of September 30, 2022, and December 31, 2021: Carrying Fair Value Level 1 Level 2 Level 3 Total September 30, 2022 Ameren: Cash, cash equivalents, and restricted cash $ 180 $ 180 $ — $ — $ 180 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 1,221 — 1,221 — 1,221 Long-term debt (including current portion) (a) 13,732 (b) — 11,493 446 (c) 11,939 Ameren Missouri: Cash, cash equivalents, and restricted cash $ 7 $ 7 $ — $ — $ 7 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 178 — 178 — 178 Long-term debt (including current portion) (a) 6,140 (b) — 5,352 — 5,352 Ameren Illinois: Cash, cash equivalents, and restricted cash $ 166 $ 166 $ — $ — $ 166 Short-term debt 353 — 353 — 353 Long-term debt (including current portion) 4,489 (b) — 3,868 — 3,868 December 31, 2021 Ameren: Cash, cash equivalents, and restricted cash $ 155 $ 155 $ — $ — $ 155 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 545 — 545 — 545 Long-term debt (including current portion) (a) 13,067 (b) — 13,930 591 (c) 14,521 Ameren Missouri: Cash, cash equivalents, and restricted cash $ 8 $ 8 $ — $ — $ 8 Investments in industrial development revenue bonds (a) 248 — 248 — 248 Short-term debt 165 — 165 — 165 Long-term debt (including current portion) (a) 5,619 (b) — 6,321 — 6,321 Ameren Illinois: Cash, cash equivalents, and restricted cash $ 133 $ 133 $ — $ — $ 133 Short-term debt 103 — 103 — 103 Long-term debt (including current portion) 4,392 (b) — 4,971 — 4,971 (a) Ameren and Ameren Missouri have investments in industrial development revenue bonds, classified as held-to-maturity and recorded in “Other Assets,” that are equal to the finance obligations for the Peno Creek and Audrain CT energy centers. As of September 30, 2022, and December 31, 2021, the carrying amount of both the investments in industrial development revenue bonds and the finance obligations approximated fair value. (b) Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $99 million, $42 million, and $41 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of September 30, 2022. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $94 million, $38 million, and $39 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2021. (c) The Level 3 fair value amount consists of ATXI’s senior unsecured notes. |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Related Party Transactions [Abstract] | |
Schedule of Affiliate Receivables and Payables | The following table presents the affiliate balances related to income taxes for Ameren Missouri and Ameren Illinois as of September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Income taxes payable to parent (a) $ — $ 72 $ — $ 8 Income taxes receivable from parent (b) 12 — 27 18 (a) Included in “Accounts payable – affiliates” on the balance sheet. (b) Included in “Accounts receivable – affiliates” on the balance sheet. |
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 nine months ended September 30, 2022 and 2021: Three Months Nine Months Agreement Income Statement Ameren Ameren Ameren Ameren Ameren Missouri power supply Operating Revenues 2022 $ 2 $ (a) $ 7 $ (a) agreements with Ameren Illinois 2021 5 (a) 10 (a) Ameren Missouri and Ameren Illinois Operating Revenues 2022 $ 6 $ (b) $ 18 $ (b) rent and facility services 2021 6 (b) 20 (b) Ameren Missouri and Ameren Illinois miscellaneous Operating Revenues 2022 $ (b) $ (b) $ (b) $ 1 services 2021 (b) 3 (b) 5 Total Operating Revenues 2022 $ 8 $ (b) $ 25 $ 1 2021 11 3 30 5 Ameren Illinois power supply Purchased Power 2022 $ (a) $ 2 $ (a) $ 7 agreements with Ameren Missouri 2021 (a) 5 (a) 10 Ameren Missouri and Ameren Illinois Purchased Power 2022 $ 1 $ (b) $ 1 $ (b) transmission services from ATXI 2021 1 (b) 3 1 Total Purchased Power 2022 $ 1 $ 2 $ 1 $ 7 2021 1 5 3 11 Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2022 $ (b) $ 1 $ (b) $ 2 rent and facility services 2021 (b) 1 (b) 3 Ameren Services support services Other Operations and Maintenance 2022 $ 38 $ 36 $ 109 $ 103 agreement 2021 41 37 110 101 Total Other Operations and 2022 $ 38 $ 37 $ 109 $ 105 Maintenance 2021 41 38 110 104 Money pool borrowings (advances) (Interest Charges)/Other Income, Net 2022 $ (b) $ (b) $ (b) $ (b) 2021 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Callaway Energy Center (Tables)
Callaway Energy Center (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Nuclear Waste Matters [Abstract] | |
Schedule of Insurance Coverage at Callaway Energy Center | The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at September 30, 2022: Type and Source of Coverage Most Recent Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers January 1, 2022 $ 450 $ — Pool participation (a) 13,210 (a) 138 (b) $ 13,660 (c) $ 138 Property damage: NEIL and EMANI April 1, 2022 $ 3,200 (d) $ 26 (e) Accidental outage: NEIL April 1, 2022 $ 490 (f) $ 7 (e) (a) Provided through mandatory participation in an industrywide retrospective premium assessment program. The maximum coverage available is dependent on the number of United States commercial reactors participating in the program. (b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $450 million in the event of an incident at any licensed United States commercial reactor, payable at $21 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. This limit is subject to change to account for the effects of inflation and changes in the number of licensed power reactors. (d) NEIL provides $2.7 billion in property damage, stabilization, decontamination, and premature decommissioning insurance for radiation events and $2.3 billion in property damage insurance for nonradiation events. EMANI provides $490 million in property damage insurance for both radiation and nonradiation events. (e) All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. (f) Accidental outage insurance provides for lost sales in the event of a prolonged accidental outage. Weekly indemnity up to $4.5 million for 52 weeks, which commences after the first 12 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 limited to $328 million. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Retirement Benefits [Abstract] | |
Components Of Net Periodic Benefit Cost | The following table presents the components of the net periodic benefit cost (income) incurred for Ameren’s pension and postretirement benefit plans for the three and nine months ended September 30, 2022 and 2021: Pension Benefits Postretirement Benefits Three Months Nine Months Three Months Nine Months 2022 2021 2022 2021 2022 2021 2022 2021 Service cost (a) $ 31 $ 33 $ 95 $ 100 $ 5 $ 5 $ 15 $ 17 Non-service cost components: Interest cost 42 38 123 114 8 9 25 25 Expected return on plan assets (80) (74) (240) (223) (21) (20) (64) (60) Amortization of: Prior service benefit — — — — (1) (1) (3) (3) Actuarial loss (gain) 7 18 19 55 (5) (1) (14) (4) Total non-service cost components (b) $ (31) $ (18) $ (98) $ (54) $ (19) $ (13) $ (56) $ (42) Net periodic benefit cost (income) (c) $ — $ 15 $ (3) $ 46 $ (14) $ (8) $ (41) $ (25) (a) Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income. (b) Non-service cost components are reflected in “Other Income, Net” on Ameren’s statement of income. See Note 5 – Other Income, Net, for additional information. (c) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. |
Summary Of Benefit Plan Costs Incurred | Ameren Missouri and Ameren Illinois are responsible for their respective share of Ameren’s pension and other postretirement costs. The following table presents the respective share of net periodic pension and other postretirement benefit costs (income) incurred for the three and nine months ended September 30, 2022 and 2021: Pension Benefits Postretirement Benefits Three Months Nine Months Three Months Nine Months 2022 2021 2022 2021 2022 2021 2022 2021 Ameren Missouri (a) $ — $ 7 $ (2) $ 22 $ (3) $ (1) $ (10) $ (3) Ameren Illinois 1 8 2 25 (11) (8) (31) (23) Other (1) — (3) (1) — 1 — 1 Ameren (a) $ — $ 15 $ (3) $ 46 $ (14) $ (8) $ (41) $ (25) (a) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. |
Income Taxes Income Taxes (Tabl
Income Taxes Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Income Tax Disclosure [Abstract] | |
Schedule of Effective Income Tax Rate Reconciliation | The following table presents a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the three and nine months ended September 30, 2022 and 2021: Ameren Ameren Missouri Ameren Illinois 2022 2021 2022 2021 2022 2021 Three Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of deferred investment tax credit — (1) (1) (1) — — Amortization of excess deferred taxes (a) (8) (8) (15) (17) (2) (2) Depreciation differences — — — — — (1) Renewable and other tax credits (b) (4) (2) (10) (8) — — State tax 4 4 3 4 7 7 Stock-based compensation 1 — — — — — Cash surrender value of COLI 1 — — — — — Effective income tax rate 15 % 14 % (2) % (1) % 26 % 25 % Nine Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of deferred investment tax credit — — (1) — — — Amortization of excess deferred taxes (a) (8) (9) (15) (17) (2) (3) Renewable and other tax credits (b) (4) (3) (10) (8) — — State tax 5 5 3 3 7 7 Stock-based compensation — (1) — — — — Effective income tax rate 14 % 13 % (2) % (1) % 26 % 25 % (a) Reflects the amortization of amounts resulting from the revaluation of deferred income taxes subject to regulatory ratemaking, which are being refunded to customers. Deferred income taxes are revalued when federal or state income tax rates change, and the offset to the revaluation of deferred income taxes subject to regulatory ratemaking is recorded to a regulatory asset or liability. (b) Includes credits associated with the High Prairie and Atchison renewable energy centers. Ameren Missouri placed the High Prairie Renewable Energy Center in service in December 2020. Additionally, Ameren Missouri placed in service the wind turbines at its Atchison Renewable Energy Center throughout the first half of 2021. The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM. |
Supplemental Information (Table
Supplemental Information (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Supplemental Information [Abstract] | |
Schedule of Cash and Cash Equivalents Including Restricted Cash | The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets and the statements of cash flows at September 30, 2022, and December 31, 2021: September 30, 2022 December 31, 2021 Ameren Ameren Ameren Ameren Ameren Ameren “Cash and cash equivalents” $ 7 $ — $ — $ 8 $ — $ — Restricted cash included in “Other current assets” 7 3 4 16 4 6 Restricted cash included in “Other assets” 162 — 162 127 — 127 Restricted cash included in “Nuclear decommissioning trust fund” 4 4 — 4 4 — Total cash, cash equivalents, and restricted cash $ 180 $ 7 $ 166 $ 155 $ 8 $ 133 |
Schedule of Accounts, Notes, Loans and Financing Receivable | The following table provides a reconciliation of the beginning and ending amount of the allowance for doubtful accounts for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren: Beginning of period $ 30 $ 42 $ 29 $ 50 Bad debt expense 15 7 26 8 Net write-offs (14) (13) (24) (22) End of period $ 31 $ 36 $ 31 $ 36 Ameren Missouri: Beginning of period $ 12 $ 16 $ 13 $ 16 Bad debt expense 3 2 6 5 Net write-offs (3) (4) (7) (7) End of period $ 12 $ 14 $ 12 $ 14 Ameren Illinois: (a) Beginning of period $ 18 $ 26 $ 16 $ 34 Bad debt expense 12 5 20 3 (b) Net write-offs (11) (9) (17) (15) End of period $ 19 $ 22 $ 19 $ 22 (a) Ameren Illinois has rate-adjustment mechanisms that allow it to recover the difference between its actual net bad debt write-offs under GAAP, including those associated with receivables purchased from alternative retail electric suppliers, and the amount of net bad debt write-offs included in its base rates. (b) In the nine months ended September 30, 2021, Ameren Illinois’ bad debt expense was reduced as a result of state funding received for customer bill assistance. |
Schedule of Cash Flow, Supplemental Disclosures | The following table provides noncash financing and investing activity excluded from the statements of cash flows for the nine months ended September 30, 2022 and 2021: September 30, 2022 September 30, 2021 Ameren Ameren Ameren Ameren Ameren Ameren Investing Accrued capital expenditures $ 367 $ 187 $ 180 $ 396 $ 209 $ 182 Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund (262) (262) — 85 85 — Financing Issuance of common stock for stock-based compensation $ 31 $ — $ — $ 33 $ — $ — Issuance of common stock under the DRPlus 8 — — — — — |
Asset Retirement Obligation Disclosure | The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the nine months ended September 30, 2022: Ameren Ameren Ameren Balance at December 31, 2021 $ 760 (a) $ 4 (b) $ 764 (a) Liabilities incurred 1 — 1 Liabilities settled (3) — (3) Accretion 23 (c) — 23 (c) Change in estimates (7) — (7) Balance at September 30, 2022 $ 774 (a) $ 4 (b) $ 778 (a) (a) Balance included $7 million in “Other current liabilities” on the balance sheet as of both September 30, 2022, and December 31, 2021. (b) Included in “Other deferred credits and liabilities” on the balance sheet. (c) Accretion expense attributable to Ameren Missouri was recorded as a decrease to regulatory liabilities. |
Schedule of excise taxes | The following table presents the excise taxes recorded on a gross basis in “Operating Revenues – Electric,” “Operating Revenues – Natural gas” and “Operating Expenses – Taxes other than income taxes” on the statements of income for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Ameren Missouri $ 55 $ 54 $ 128 $ 120 Ameren Illinois 28 27 101 93 Ameren $ 83 $ 81 $ 229 $ 213 |
Schedule of Earnings Per Share, Basic and Diluted | The following table reconciles the basic weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding for the three and nine months ended September 30, 2022 and 2021: Three Months Nine Months 2022 2021 2022 2021 Weighted-average Common Shares Outstanding – Basic 258.4 257.3 258.2 255.9 Assumed settlement of performance share units and restricted stock units 0.9 1.3 1.0 1.3 Dilutive effect of forward sale agreements 0.2 — 0.1 — Weighted-average Common Shares Outstanding – Diluted (a) 259.5 258.6 259.3 257.2 (a) There was an immaterial number of anti-dilutive securities excluded from the earnings per diluted share calculations for the three and nine months ended September 30, 2022 and 2021. |
Segment Information (Tables)
Segment Information (Tables) | 9 Months Ended |
Sep. 30, 2022 | |
Segment Reporting [Abstract] | |
Schedule Of Segment Reporting Information By Segment | The following tables present revenues, net income attributable to common shareholders, and capital expenditures by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 2022 and 2021. Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount. For additional information about our segments, see Note 16 – Segment Information under Part II, Item 8, of the Form 10-K. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Other Intersegment Eliminations Ameren Three Months 2022: External revenues $ 1,351 $ 672 $ 146 $ 137 $ — $ — $ 2,306 Intersegment revenues 8 — — 32 — (40) — Net income (loss) attributable to Ameren common shareholders 397 51 (4) 78 (a) (70) — 452 Capital expenditures 431 163 114 187 1 3 899 Three Months 2021: External revenues $ 1,118 $ 425 $ 127 $ 141 $ — $ — $ 1,811 Intersegment revenues 11 3 — 19 — (33) — Net income (loss) attributable to Ameren common shareholders 375 36 (8) 73 (a) (51) — 425 Capital expenditures 466 (b) 143 93 154 2 (8) 850 (b) Nine Months 2022: External revenues $ 3,071 $ 1,640 $ 811 $ 389 $ — $ — $ 5,911 Intersegment revenues 25 1 — 76 — (102) — Net income (loss) attributable to Ameren common shareholders 547 151 82 199 (a) (68) — 911 Capital expenditures 1,237 444 232 519 4 1 2,437 Nine Months 2021: External revenues $ 2,612 $ 1,222 $ 642 $ 373 $ — $ — $ 4,849 Intersegment revenues 30 5 — 53 — (88) — Net income (loss) attributable to Ameren common shareholders 533 123 75 175 (a) (41) — 865 Capital expenditures 1,567 (b) 429 202 426 3 (14) 2,613 (b) (a) Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent). (b) Includes $98 million and $515 million at Ameren and Ameren Missouri for wind generation expenditures for the three and nine months ended September 30, 2021, respectively. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2022: External revenues $ 672 $ 146 $ 86 $ — $ 904 Intersegment revenues — — 31 (31) — Net income (loss) available to common shareholder 51 (4) 56 — 103 Capital expenditures 163 114 169 — 446 Three Months 2021: External revenues $ 428 $ 127 $ 90 $ — $ 645 Intersegment revenues — — 18 (18) — Net income (loss) available to common shareholder 36 (8) 51 — 79 Capital expenditures 143 93 144 — 380 Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Nine Months 2022: External revenues $ 1,641 $ 811 $ 245 $ — $ 2,697 Intersegment revenues — — 75 (75) — Net income available to common shareholder 151 82 142 — 375 Capital expenditures 444 232 469 — 1,145 Nine Months 2021: External revenues $ 1,227 $ 642 $ 228 $ — $ 2,097 Intersegment revenues — — 49 (49) — Net income available to common shareholder 123 75 116 — 314 Capital expenditures 429 202 395 — 1,026 |
Disaggregation of Revenue | The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 2022 and 2021. Economic factors affect the nature, timing, amount, and uncertainty of revenues and cash flows in a similar manner across customer classes. Revenues from alternative revenue programs have a similar distribution among customer classes as revenues from contracts with customers. Other revenues not associated with contracts with customers are presented in the Other customer classification, along with electric transmission and off-system revenues. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2022: Residential $ 564 $ 407 $ — $ — $ — $ 971 Commercial 430 233 — — — 663 Industrial 99 47 — — — 146 Other 245 (15) — 169 (39) 360 Total electric revenues $ 1,338 $ 672 $ — $ 169 $ (39) $ 2,140 Residential $ 11 $ — $ 89 $ — $ — $ 100 Commercial 6 — 25 — — 31 Industrial 1 — 5 — — 6 Other 3 — 27 — (1) 29 Total natural gas revenues $ 21 $ — $ 146 $ — $ (1) $ 166 Total revenues (a) $ 1,359 $ 672 $ 146 $ 169 $ (40) $ 2,306 Three Months 2021: Residential $ 537 $ 258 $ — $ — $ — $ 795 Commercial 412 143 — — — 555 Industrial 98 26 — — — 124 Other 66 1 — 160 (33) 194 Total electric revenues $ 1,113 $ 428 $ — $ 160 $ (33) $ 1,668 Residential $ 9 $ — $ 75 $ — $ — $ 84 Commercial 4 — 23 — — 27 Industrial — — 3 — — 3 Other 3 — 26 — — 29 Total natural gas revenues $ 16 $ — $ 127 $ — $ — $ 143 Total revenues (a) $ 1,129 $ 428 $ 127 $ 160 $ (33) $ 1,811 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Nine Months 2022: Residential $ 1,267 $ 954 $ — $ — $ — $ 2,221 Commercial 968 571 — — — 1,539 Industrial 229 145 — — — 374 Other 502 (29) — 465 (101) 837 Total electric revenues $ 2,966 $ 1,641 $ — $ 465 $ (101) $ 4,971 Residential $ 78 $ — $ 575 $ — $ — $ 653 Commercial 36 — 152 — — 188 Industrial 4 — 33 — — 37 Other 12 — 51 — (1) 62 Total natural gas revenues $ 130 $ — $ 811 $ — $ (1) $ 940 Total revenues (a) $ 3,096 $ 1,641 $ 811 $ 465 $ (102) $ 5,911 Nine Months 2021: Residential $ 1,177 $ 705 $ — $ — $ — $ 1,882 Commercial 899 402 — — — 1,301 Industrial 221 94 — — — 315 Other 246 26 — 426 (88) 610 Total electric revenues $ 2,543 $ 1,227 $ — $ 426 $ (88) $ 4,108 Residential $ 54 $ — $ 438 $ — $ — $ 492 Commercial 23 — 116 — — 139 Industrial 2 — 20 — — 22 Other 20 — 68 — — 88 Total natural gas revenues $ 99 $ — $ 642 $ — $ — $ 741 Total revenues (a) $ 2,642 $ 1,227 $ 642 $ 426 $ (88) $ 4,849 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and nine months ended September 30, 2022 and 2021: Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Ameren Three Months 2022: Revenues from alternative revenue programs $ 14 $ (83) $ (3) $ (11) $ (83) Other revenues not from contracts with customers (45) (a) 2 — — (43) (a) Three Months 2021: Revenues from alternative revenue programs $ 6 $ (97) $ (5) $ 1 $ (95) Other revenues not from contracts with customers 7 (b) 6 — — 13 (b) Nine Months 2022: Revenues from alternative revenue programs $ 8 $ 13 $ (5) $ (14) $ 2 Other revenues not from contracts with customers (81) (a), (b) 5 2 — (74) (a), (b) Nine Months 2021: Revenues from alternative revenue programs $ (9) $ (2) $ — $ 5 $ (6) Other revenues not from contracts with customers 71 (b) 9 2 — 82 (b) (a) Includes net realized losses on derivative power contracts. (b) Includes insurance recoveries related to lost sales associated with the Callaway Energy Center maintenance outage. See Note 9 – Callaway Energy Center under Part II, Item 8, of the Form 10-K for additional information. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2022: Residential $ 407 $ 89 $ — $ — $ 496 Commercial 233 25 — — 258 Industrial 47 5 — — 52 Other (15) 27 117 (31) 98 Total revenues (a) $ 672 $ 146 $ 117 $ (31) $ 904 Three Months 2021: Residential $ 258 $ 75 $ — $ — $ 333 Commercial 143 23 — — 166 Industrial 26 3 — — 29 Other 1 26 108 (18) 117 Total revenues (a) $ 428 $ 127 $ 108 $ (18) $ 645 Nine Months 2022: Residential $ 954 $ 575 $ — $ — $ 1,529 Commercial 571 152 — — 723 Industrial 145 33 — — 178 Other (29) 51 320 (75) 267 Total revenues (a) $ 1,641 $ 811 $ 320 $ (75) $ 2,697 Nine Months 2021: Residential $ 705 $ 438 $ — $ — $ 1,143 Commercial 402 116 — — 518 Industrial 94 20 — — 114 Other 26 68 277 (49) 322 Total revenues (a) $ 1,227 $ 642 $ 277 $ (49) $ 2,097 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments for the three and nine months ended September 30, 2022 and 2021: Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois Three Months 2022: Revenues from alternative revenue programs $ (83) $ (3) $ (10) $ (96) Other revenues not from contracts with customers 2 — — 2 Three Months 2021: Revenues from alternative revenue programs $ (97) $ (5) $ 3 $ (99) Other revenues not from contracts with customers 6 — — 6 Nine Months 2022: Revenues from alternative revenue programs $ 13 $ (5) $ (12) $ (4) Other revenues not from contracts with customers 5 2 — 7 Nine Months 2021: Revenues from alternative revenue programs $ (2) $ — $ 4 $ 2 Other revenues not from contracts with customers 9 2 — 11 |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Unconsolidated variable interest | $ 58 | $ 56 |
Cash Surrender Value of Life Insurance | 239 | 278 |
Corporate owned life insurance, borrowings | 108 | 109 |
Ameren Illinois Company | ||
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Cash Surrender Value of Life Insurance | 116 | 117 |
Corporate owned life insurance, borrowings | 108 | $ 109 |
Partnership Funding Commitment | ||
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Outstanding funding commitments | $ 21 |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative-Missouri) (Details) $ in Millions | 3 Months Ended | 9 Months Ended | ||||
Sep. 30, 2022 USD ($) | Jun. 30, 2022 MWh | Mar. 31, 2022 MWh | Sep. 30, 2021 USD ($) | Sep. 30, 2022 USD ($) numberOfCountriesInvestigatedByTheDOC | Sep. 30, 2021 USD ($) | |
Rate And Regulatory Matters [Line Items] | ||||||
Revenues | $ 2,306 | $ 1,811 | $ 5,911 | $ 4,849 | ||
Union Electric Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Missouri Renewable Energy Standard Percentage | 15% | |||||
Missouri Renewable Energy Standard Percentage - Solar | 2% | |||||
Number of Countries Investigated by the DOC | numberOfCountriesInvestigatedByTheDOC | 4 | |||||
Union Electric Company | Pending Rate Case | Electric | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 316 | |||||
Public Utilities, Requested Return on Equity, Percentage | 10.20% | |||||
Public Utilities, Requested Equity Capital Structure, Percentage | 51.90% | |||||
Rate Base | $ 11,600 | |||||
Months to complete a rate proceeding | 11 months | |||||
Union Electric Company | Wind Generation Facility | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Amount of Megawatts | MWh | 200 | 150 | ||||
Union Electric Company | Final Rate Order | Electric | MEEIA 2019 [Domain] | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Revenues | $ 12 | $ 9 | ||||
Union Electric Company | Maximum | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
PISA Rate Increase Limit Beginning 2024 | 2.50% | |||||
Public Utilities, Approved Rate Increase (Decrease), Percentage | 2.85% | |||||
Percentage of energy sourced from renewable resources | 100% |
Rate And Regulatory Matters (_2
Rate And Regulatory Matters (Narrative-Illinois) (Details) - Ameren Illinois Company $ in Millions | 9 Months Ended |
Sep. 30, 2022 USD ($) numberOfProposedPerformanceMetrics | |
Rate And Regulatory Matters [Line Items] | |
Annual investment in energy-efficiency programs | $ 120 |
Minimum | |
Rate And Regulatory Matters [Line Items] | |
ICC required RTO cost benefit study duration | 5 years |
Maximum | |
Rate And Regulatory Matters [Line Items] | |
ICC required RTO cost benefit study duration | 10 years |
Electric Distribution | |
Rate And Regulatory Matters [Line Items] | |
Requested Return on Equity Adjustment | 0.24% |
Number of Proposed Performance Metrics | numberOfProposedPerformanceMetrics | 7 |
Electric Distribution | Minimum | |
Rate And Regulatory Matters [Line Items] | |
Return on equity adjustment | 0.20% |
Electric Distribution | Maximum | |
Rate And Regulatory Matters [Line Items] | |
Return on equity adjustment | 0.60% |
Pending Rate Case | Electric Distribution | IEIMA | |
Rate And Regulatory Matters [Line Items] | |
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 84 |
Public Utilities, Requested Equity Capital Structure, Percentage | 54% |
ICC Staff Recommended Rate Increase (Decrease) | $ 61 |
ICC Staff Recommended Equity Capital Structure, Percentage | 50% |
Pending Rate Case | Electric Distribution | FEJA energy-efficiency rider | |
Rate And Regulatory Matters [Line Items] | |
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 17 |
ICC Staff Recommended Rate Increase (Decrease) | 15 |
Pending Rate Case | Natural gas | |
Rate And Regulatory Matters [Line Items] | |
Natural Gas Capital Investment Prudency Challenge | 70 |
Challenged Recoveries Under the QIP | 3 |
IETL | |
Rate And Regulatory Matters [Line Items] | |
Energy Transition Assistance Fund Surcharge | $ 50 |
Rate And Regulatory Matters (_3
Rate And Regulatory Matters (Narrative-Federal) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 9 Months Ended | |||
May 31, 2020 | Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | Dec. 31, 2021 | |
Rate And Regulatory Matters [Line Items] | ||||||
Regulatory liabilities | $ 5,658 | $ 5,658 | $ 5,848 | |||
Revenues | 2,306 | $ 1,811 | 5,911 | $ 4,849 | ||
Ameren Illinois Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Regulatory liabilities | 2,532 | 2,532 | $ 2,374 | |||
Revenues | 904 | $ 645 | 2,697 | $ 2,097 | ||
Final Rate Order | Ameren Illinois Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Regulatory liabilities | $ 9 | 9 | ||||
Midwest Independent Transmission System Operator, Inc | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Revenues | 17 | |||||
Midwest Independent Transmission System Operator, Inc | Ameren Illinois Company | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Revenues | $ 11 | |||||
Midwest Independent Transmission System Operator, Inc | Final Rate Order | ||||||
Rate And Regulatory Matters [Line Items] | ||||||
Approved return on equity percentage | 10.02% |
Short-Term Debt And Liquidity_2
Short-Term Debt And Liquidity (Narrative) (Details) $ in Billions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 USD ($) | Sep. 30, 2021 | Sep. 30, 2022 USD ($) | Sep. 30, 2021 | |
Credit Agreements | ||||
Short-term Debt [Line Items] | ||||
Net Liquidity Available | $ 1.1 | $ 1.1 | ||
Actual debt-to-capital ratio | 0.59 | 0.59 | ||
Utilities | ||||
Short-term Debt [Line Items] | ||||
Short-term Debt, Weighted Average Interest Rate, over Time | 2.48% | 0.06% | 1.29% | 0.17% |
Union Electric Company | Missouri Credit Agreement | ||||
Short-term Debt [Line Items] | ||||
Actual debt-to-capital ratio | 0.49 | 0.49 | ||
Ameren Illinois Company | Illinois Credit Agreement | ||||
Short-term Debt [Line Items] | ||||
Actual debt-to-capital ratio | 0.45 | 0.45 |
Short-Term Debt and Liquidity_3
Short-Term Debt and Liquidity (Short-Term Debt outstanding) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Short-term Debt [Line Items] | ||
Short-term debt | $ 1,221 | $ 545 |
Union Electric Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 178 | 165 |
Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 353 | 103 |
Commercial Paper | ||
Short-term Debt [Line Items] | ||
Short-term debt | 1,221 | 545 |
Commercial Paper | Parent Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 690 | 277 |
Commercial Paper | Union Electric Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 178 | 165 |
Commercial Paper | Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | $ 353 | $ 103 |
Short-Term Debt and Liquidity_4
Short-Term Debt and Liquidity (Short-Term Debt Activity) (Details) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2022 | Sep. 30, 2021 | |
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 791 | $ 665 |
Weighted-average interest rate | 1.47% | 0.22% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 1,222 | $ 1,134 |
Peak interest rate | 3.60% | 0.33% |
Parent Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 439 | $ 404 |
Weighted-average interest rate | 1.58% | 0.23% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 690 | $ 650 |
Peak interest rate | 3.55% | 0.33% |
Union Electric Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 253 | $ 121 |
Weighted-average interest rate | 1.16% | 0.22% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 539 | $ 546 |
Peak interest rate | 3.55% | 0.25% |
Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 99 | $ 140 |
Weighted-average interest rate | 1.77% | 0.22% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 354 | $ 485 |
Peak interest rate | 3.60% | 0.25% |
Long-Term debt and Equity Fin_2
Long-Term debt and Equity Financings (Details) $ / shares in Units, shares in Millions | 1 Months Ended | 3 Months Ended | 9 Months Ended | ||||||
Aug. 31, 2022 USD ($) | Apr. 30, 2022 USD ($) | Sep. 30, 2022 USD ($) shares | Mar. 31, 2022 USD ($) shares | Sep. 30, 2021 shares | Sep. 30, 2022 USD ($) $ / shares shares | Sep. 30, 2021 USD ($) shares | Aug. 29, 2022 USD ($) | May 31, 2021 USD ($) | |
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Shares issued under the DRPlus and 401(k) plan | shares | 0.1 | 0.1 | 0.4 | 0.4 | |||||
Issuances of common stock | $ 29,000,000 | $ 297,000,000 | |||||||
Stock Issued During Period, Shares, Other | shares | 0 | 0.4 | 0 | 0.4 | 0.5 | ||||
Stock Issued During Period, Value, Other | $ 31,000,000 | ||||||||
Maximum Value Of Shares To Be Issued Under ATM Program | $ 750,000,000 | ||||||||
Forward Contract Indexed to Issuer's Equity, Basis Spread | 75 | 75 | |||||||
Minimum | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares | $ 86.35 | ||||||||
Maximum | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares | 94.80 | ||||||||
Weighted Average | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares | $ 90.31 | ||||||||
Dividend reinvestment and 401 (k) plans | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Issuances of common stock | $ 4,000,000 | $ 29,000,000 | |||||||
Accrued Proceeds from Issuance of Common Stock | $ 8,000,000 | ||||||||
Forward Sale Agreements Outstanding | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Forward Contract Indexed to Issuer's Equity, Indexed Shares (in shares) | shares | 6.6 | 6.6 | |||||||
Forward Contract Indexed to Issuer's Equity, Settlement Alternatives, Shares, at Fair Value | shares | 6.6 | 6.6 | |||||||
Forward Contract Indexed to Issuer's Equity, Settlement Alternatives, Cash, at Fair Value | $ 587,000,000 | $ 587,000,000 | |||||||
Period End Net Cash Settlement Price | 58,000,000 | 58,000,000 | |||||||
Period End Net Share Settlement Price | 700,000 | 700,000 | |||||||
Forward Sale Agreement Equity Offering Shares | 6,600,000 | 6,600,000 | |||||||
Forward Sale Agreement Gross Sales Price | 600,000,000 | 600,000,000 | |||||||
Forward Sale Agreement, Compensation Received by Counterparty | $ 6,000,000 | $ 6,000,000 | |||||||
Union Electric Company | Secured Debt | Senior Secured Notes 3.90% Due 2052 | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Debt Instrument, Face Amount | $ 525,000,000 | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.90% | ||||||||
Proceeds from Issuance of Secured Debt | $ 519,000,000 | ||||||||
Ameren Illinois Company | Unsecured Debt | Senior Secured Notes 3.85% Due 2032 | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Debt Instrument, Face Amount | $ 500,000,000 | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.85% | ||||||||
Proceeds from Issuance of Secured Debt | $ 496,000,000 | ||||||||
Ameren Illinois Company | Unsecured Debt | Senior Secured Notes 2.70% Due 2022 | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Debt Instrument, Face Amount | $ 400,000,000 | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.70% | ||||||||
Ameren Transmission Company of Illinois | Unsecured Debt | Senior Unsecured Notes, 2.96%, Due 2052 | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Debt Instrument, Face Amount | $ 95,000,000 | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.96% | 2.96% | |||||||
Proceeds from Issuance of Debt | $ 95,000,000 | ||||||||
Ameren Transmission Company of Illinois | Unsecured Debt | Senior Unsecured Notes, 3.43%, Due 2050 | |||||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.43% | 3.43% | |||||||
Long-Term Debt, Maturity, Year One | $ 50,000,000 | $ 50,000,000 |
Other Income, Net (Details)
Other Income, Net (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | $ 12 | $ 14 | $ 31 | $ 30 |
Interest income on industrial development revenue bonds | 6 | 7 | 18 | 19 |
Non-service cost components of net periodic benefit income | 45 | 34 | 138 | 102 |
Miscellaneous income | 5 | 1 | 14 | 7 |
Income (Loss) from Equity Method Investments | (3) | 2 | 1 | 8 |
Donations | (1) | (1) | (5) | (5) |
Miscellaneous expense | (6) | (1) | (17) | (10) |
Total Other Income, Net | 58 | 56 | 180 | 151 |
Union Electric Company | ||||
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | 7 | 7 | 17 | 17 |
Interest income on industrial development revenue bonds | 6 | 7 | 18 | 19 |
Non-service cost components of net periodic benefit income | 13 | 13 | 41 | 41 |
Miscellaneous income | 2 | 2 | 5 | 3 |
Donations | 0 | 0 | (2) | (1) |
Miscellaneous expense | (3) | (2) | (7) | (5) |
Total Other Income, Net | 25 | 27 | 72 | 74 |
Defined Benefit Plan, Non-service Cost or Income Components - Tracker | 5 | (3) | 16 | (6) |
Ameren Illinois Company | ||||
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | 5 | 7 | 14 | 13 |
Non-service cost components of net periodic benefit income | 21 | 13 | 63 | 41 |
Miscellaneous income | 4 | 0 | 9 | 4 |
Donations | (1) | (1) | (3) | (4) |
Miscellaneous expense | (3) | 0 | (8) | (5) |
Total Other Income, Net | $ 26 | $ 19 | $ 75 | $ 49 |
Derivative Financial Instrume_3
Derivative Financial Instruments (Open Gross Derivative Volumes By Commodity Type) (Detail) lb in Thousands, gal in Millions, MWh in Millions, MMBTU in Millions | 9 Months Ended | 12 Months Ended |
Sep. 30, 2022 MWh MMBTU lb gal | Dec. 31, 2021 MMBTU MWh lb gal | |
Fuel oils | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Volume | gal | 19 | 30 |
Natural gas | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU | 187 | 179 |
Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 8 | 12 |
Uranium | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Mass | lb | 406 | 586 |
Union Electric Company | Fuel oils | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Volume | gal | 19 | 30 |
Union Electric Company | Natural gas | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU | 43 | 35 |
Union Electric Company | Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 2 | 6 |
Union Electric Company | Uranium | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Mass | lb | 406 | 586 |
Ameren Illinois Company | Fuel oils | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Volume | gal | 0 | 0 |
Ameren Illinois Company | Natural gas | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU | 144 | 144 |
Ameren Illinois Company | Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 6 | 6 |
Ameren Illinois Company | Uranium | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Mass | lb | 0 | 0 |
Derivative Financial Instrume_4
Derivative Financial Instruments (Derivative Instruments Carrying Value) (Detail) - Not Designated As Hedging Instrument - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Derivative [Line Items] | ||
Derivative assets | $ 167 | $ 90 |
Derivative Liability | 177 | 202 |
Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 12 | 8 |
Fuel oils | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 3 | 5 |
Fuel oils | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 0 |
Natural gas | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 71 | 35 |
Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 34 | 18 |
Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 4 | 3 |
Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 11 | 8 |
Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 39 | 23 |
Power | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 5 | 0 |
Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 50 | 131 |
Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 111 | 59 |
Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 2 | 0 |
Uranium | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 1 |
Uranium | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 1 |
Union Electric Company | ||
Derivative [Line Items] | ||
Derivative assets | 73 | 49 |
Derivative Liability | 129 | 77 |
Union Electric Company | Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 12 | 8 |
Union Electric Company | Fuel oils | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 3 | 5 |
Union Electric Company | Fuel oils | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 0 |
Union Electric Company | Natural gas | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 14 | 7 |
Union Electric Company | Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 13 | 5 |
Union Electric Company | Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 1 |
Union Electric Company | Natural gas | Mark-to-market derivative liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 2 | 2 |
Union Electric Company | Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 0 |
Union Electric Company | Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 28 | 23 |
Union Electric Company | Power | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Union Electric Company | Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 14 | 23 |
Union Electric Company | Power | Mark-to-market derivative liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 111 | 50 |
Union Electric Company | Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 0 |
Union Electric Company | Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 2 | 0 |
Union Electric Company | Uranium | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 1 |
Union Electric Company | Uranium | Mark-to-market derivative liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 1 |
Union Electric Company | Uranium | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 0 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Derivative assets | 94 | 41 |
Derivative Liability | 48 | 125 |
Ameren Illinois Company | Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Fuel oils | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Fuel oils | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Natural gas | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 21 | 13 |
Ameren Illinois Company | Natural gas | Mark-to-market derivative assets | ||
Derivative [Line Items] | ||
Derivative assets | 57 | 28 |
Ameren Illinois Company | Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 3 | 2 |
Ameren Illinois Company | Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 9 | 6 |
Ameren Illinois Company | Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Power | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 5 | 0 |
Ameren Illinois Company | Power | Mark-to-market derivative assets | ||
Derivative [Line Items] | ||
Derivative assets | 11 | 0 |
Ameren Illinois Company | Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 36 | 108 |
Ameren Illinois Company | Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 9 |
Ameren Illinois Company | Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Uranium | Other assets | ||
Derivative [Line Items] | ||
Derivative assets | 0 | 0 |
Ameren Illinois Company | Uranium | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | $ 0 | $ 0 |
Derivative Financial Instrume_5
Derivative Financial Instruments (Offsetting Assets and Liabilities) (Details) - Not Designated As Hedging Instrument - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | $ 167 | $ 90 |
Gross derivative instruments not offset in the balance sheet | 31 | 19 |
Gross cash collateral received not offset in the balance sheet | 3 | 0 |
Net derivative asset | 133 | 71 |
Gross derivative liability amount recognized on the balance sheet | 177 | 202 |
Gross derivative instruments not offset in the balance sheet | 31 | 19 |
Gross cash collateral posted not offset in the balance sheet | 99 | 47 |
Net derivative liability | 47 | 136 |
Union Electric Company | ||
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | 73 | 49 |
Gross derivative instruments not offset in the balance sheet | 18 | 15 |
Gross cash collateral received not offset in the balance sheet | 2 | 0 |
Net derivative asset | 53 | 34 |
Gross derivative liability amount recognized on the balance sheet | 129 | 77 |
Gross derivative instruments not offset in the balance sheet | 18 | 15 |
Gross cash collateral posted not offset in the balance sheet | 99 | 47 |
Net derivative liability | 12 | 15 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | 94 | 41 |
Gross derivative instruments not offset in the balance sheet | 13 | 4 |
Gross cash collateral received not offset in the balance sheet | 1 | 0 |
Net derivative asset | 80 | 37 |
Gross derivative liability amount recognized on the balance sheet | 48 | 125 |
Gross derivative instruments not offset in the balance sheet | 13 | 4 |
Gross cash collateral posted not offset in the balance sheet | 0 | 0 |
Net derivative liability | $ 35 | $ 121 |
Derivative Financial Instrume_6
Derivative Financial Instruments (Credit Risk) (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2022 USD ($) | |
Credit Derivatives [Line Items] | |
Credit Derivative, Maximum Exposure, Undiscounted | $ 142 |
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure | 124 |
Union Electric Company | |
Credit Derivatives [Line Items] | |
Credit Derivative, Maximum Exposure, Undiscounted | 55 |
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure | 43 |
Ameren Illinois Company | |
Credit Derivatives [Line Items] | |
Credit Derivative, Maximum Exposure, Undiscounted | 87 |
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure | $ 81 |
Fair Value Measurements (Schedu
Fair Value Measurements (Schedule Of Fair Value Hierarchy Of Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | $ 901 | $ 1,152 |
Assets fair value | 1,068 | 1,242 |
Excluded receivables, payables, and accrued income, net | 9 | 7 |
Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 574 | 824 |
Assets fair value | 603 | 848 |
Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 327 | 328 |
Assets fair value | 418 | 373 |
Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Assets fair value | 47 | 21 |
Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 167 | 90 |
Derivative Liability | 177 | 202 |
Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 29 | 24 |
Derivative Liability | 99 | 45 |
Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 91 | 45 |
Derivative Liability | 8 | 7 |
Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 47 | 21 |
Derivative Liability | 70 | 150 |
Union Electric Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 901 | 1,152 |
Assets fair value | 974 | 1,201 |
Union Electric Company | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 574 | 824 |
Assets fair value | 597 | 847 |
Union Electric Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 327 | 328 |
Assets fair value | 353 | 340 |
Union Electric Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Assets fair value | 24 | 14 |
Union Electric Company | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 73 | 49 |
Derivative Liability | 129 | 77 |
Union Electric Company | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 23 | 23 |
Derivative Liability | 99 | 45 |
Union Electric Company | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 26 | 12 |
Derivative Liability | 2 | 2 |
Union Electric Company | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 24 | 14 |
Derivative Liability | 28 | 30 |
Union Electric Company | Fuel oils | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 15 | 13 |
Derivative Liability | 1 | 0 |
Union Electric Company | Fuel oils | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 13 | 13 |
Derivative Liability | 1 | 0 |
Union Electric Company | Fuel oils | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Fuel oils | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 2 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Natural gas | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 27 | 12 |
Derivative Liability | 3 | 3 |
Union Electric Company | Natural gas | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 1 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Natural gas | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 26 | 12 |
Derivative Liability | 2 | 2 |
Union Electric Company | Natural gas | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 1 | 1 |
Union Electric Company | Power | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 28 | 23 |
Derivative Liability | 125 | 73 |
Union Electric Company | Power | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 9 | 10 |
Derivative Liability | 98 | 45 |
Union Electric Company | Power | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Power | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 19 | 13 |
Derivative Liability | 27 | 28 |
Union Electric Company | Uranium | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 3 | 1 |
Derivative Liability | 0 | 1 |
Union Electric Company | Uranium | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Uranium | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Uranium | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 3 | 1 |
Derivative Liability | 0 | 1 |
Union Electric Company | Equity securities: | U.S. large capitalization | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 574 | 824 |
Union Electric Company | Equity securities: | U.S. large capitalization | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 574 | 824 |
Union Electric Company | Equity securities: | U.S. large capitalization | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Equity securities: | U.S. large capitalization | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | U.S. Treasury and agency securities | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 148 | 141 |
Union Electric Company | Debt securities: | U.S. Treasury and agency securities | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | U.S. Treasury and agency securities | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 148 | 141 |
Union Electric Company | Debt securities: | U.S. Treasury and agency securities | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | Corporate bonds | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 115 | 131 |
Union Electric Company | Debt securities: | Corporate bonds | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | Corporate bonds | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 115 | 131 |
Union Electric Company | Debt securities: | Corporate bonds | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | Other Debt Securities | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 64 | 56 |
Union Electric Company | Debt securities: | Other Debt Securities | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Union Electric Company | Debt securities: | Other Debt Securities | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 64 | 56 |
Union Electric Company | Debt securities: | Other Debt Securities | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Ameren Illinois Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 94 | 41 |
Ameren Illinois Company | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 6 | 1 |
Ameren Illinois Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 65 | 33 |
Ameren Illinois Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 23 | 7 |
Ameren Illinois Company | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 48 | 125 |
Ameren Illinois Company | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 6 | 5 |
Ameren Illinois Company | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 42 | 120 |
Ameren Illinois Company | Natural gas | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 78 | 41 |
Derivative Liability | 12 | 8 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 6 | 1 |
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 65 | 33 |
Derivative Liability | 6 | 5 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 7 | 7 |
Derivative Liability | 6 | 3 |
Ameren Illinois Company | Power | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 16 | 0 |
Derivative Liability | 36 | 117 |
Ameren Illinois Company | Power | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Power | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 0 | 0 |
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Power | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative assets | 16 | 0 |
Derivative Liability | $ 36 | $ 117 |
Fair Value Measurements (Sche_2
Fair Value Measurements (Schedule Of Changes In The Fair Value Of Financial Assets And Liabilities Classified As Level Three In The Fair Value Hierarchy) (Details) - Power - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | $ (80) | $ (171) | $ (132) | $ (196) |
Included in regulatory assets/liabilities | 20 | 3 | 49 | 21 |
Settlements, assets | 32 | 1 | 55 | 8 |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 25 | 2 | 61 | 21 |
Ending balance | (28) | (167) | (28) | (167) |
Union Electric Company | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (36) | (5) | (15) | 2 |
Included in regulatory assets/liabilities | (10) | (16) | (56) | (22) |
Settlements, assets | 38 | 63 | ||
Settlement, liabilities | (2) | (3) | ||
Change in unrealized gains (losses) related to assets/liabilities held at period end | (3) | (17) | (39) | (21) |
Ending balance | (8) | (23) | (8) | (23) |
Ameren Illinois Company | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (44) | (166) | (117) | (198) |
Included in regulatory assets/liabilities | 30 | 19 | 105 | 43 |
Settlements, assets | 3 | 11 | ||
Settlement, liabilities | (6) | (8) | ||
Change in unrealized gains (losses) related to assets/liabilities held at period end | 28 | 19 | 100 | 42 |
Ending balance | $ (20) | $ (144) | $ (20) | $ (144) |
Fair Value Measurements (Sche_3
Fair Value Measurements (Schedule Of Valuation Process And Unobservable Inputs) (Details) - Power $ in Millions | Sep. 30, 2022 USD ($) $ / MWh $ / MMBTU | Dec. 31, 2021 USD ($) $ / MWh $ / MMBTU |
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Derivative assets | $ | $ 35 | $ 13 |
Derivative liabilities | $ | $ (63) | $ (145) |
Commodity Forward Price | Discounted cash flow | Minimum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 42 | 32 |
Commodity Forward Price | Discounted cash flow | Maximum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 118 | 55 |
Commodity Forward Price | Discounted cash flow | Weighted Average | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 60 | 40 |
Nodal Basis | Discounted cash flow | Minimum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | (15) | (14) |
Nodal Basis | Discounted cash flow | Maximum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 2 | 0 |
Nodal Basis | Discounted cash flow | Weighted Average | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | (5) | (2) |
Commodity Future Price | Discounted cash flow | Minimum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | $ / MMBTU | 0 | |
Commodity Future Price | Discounted cash flow | Maximum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | $ / MMBTU | 1 | |
Commodity Future Price | Discounted cash flow | Weighted Average | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | $ / MMBTU | 0 | 0 |
Fair Value Measurements (Sche_4
Fair Value Measurements (Schedule Of Carrying Amounts And Estimated Fair Values Of Financial Assets and Liabilities) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 | Sep. 30, 2021 | Dec. 31, 2020 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | $ 180 | $ 155 | $ 145 | $ 301 |
Short-term debt | 1,221 | 545 | ||
Union Electric Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 7 | 8 | 11 | 145 |
Short-term debt | 178 | 165 | ||
Ameren Illinois Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 166 | 133 | $ 122 | $ 147 |
Short-term debt | 353 | 103 | ||
Carrying Amount | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 180 | 155 | ||
Investments in industrial development revenue bonds | 248 | 248 | ||
Short-term debt | 1,221 | 545 | ||
Long-term debt (including current portion) | 13,732 | 13,067 | ||
Debt Issuance Costs, Net | 99 | 94 | ||
Carrying Amount | Union Electric Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 7 | 8 | ||
Investments in industrial development revenue bonds | 248 | 248 | ||
Short-term debt | 178 | 165 | ||
Long-term debt (including current portion) | 6,140 | 5,619 | ||
Debt Issuance Costs, Net | 42 | 38 | ||
Carrying Amount | Ameren Illinois Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 166 | 133 | ||
Short-term debt | 353 | 103 | ||
Long-term debt (including current portion) | 4,489 | 4,392 | ||
Debt Issuance Costs, Net | 41 | 39 | ||
Fair Value | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 180 | 155 | ||
Investments, Fair Value Disclosure | 248 | 248 | ||
Short-term Debt, Fair Value | 1,221 | 545 | ||
Long-term Debt, Fair Value | 11,939 | 14,521 | ||
Fair Value | Level 1 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 180 | 155 | ||
Investments, Fair Value Disclosure | 0 | 0 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | 0 | 0 | ||
Fair Value | Level 2 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Investments, Fair Value Disclosure | 248 | 248 | ||
Short-term Debt, Fair Value | 1,221 | 545 | ||
Long-term Debt, Fair Value | 11,493 | 13,930 | ||
Fair Value | Level 3 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Investments, Fair Value Disclosure | 0 | 0 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | 446 | 591 | ||
Fair Value | Union Electric Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 7 | 8 | ||
Investments, Fair Value Disclosure | 248 | 248 | ||
Short-term Debt, Fair Value | 178 | 165 | ||
Long-term Debt, Fair Value | 5,352 | 6,321 | ||
Fair Value | Union Electric Company | Level 1 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 7 | 8 | ||
Investments, Fair Value Disclosure | 0 | 0 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | 0 | 0 | ||
Fair Value | Union Electric Company | Level 2 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Investments, Fair Value Disclosure | 248 | 248 | ||
Short-term Debt, Fair Value | 178 | 165 | ||
Long-term Debt, Fair Value | 5,352 | 6,321 | ||
Fair Value | Union Electric Company | Level 3 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Investments, Fair Value Disclosure | 0 | 0 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | 0 | 0 | ||
Fair Value | Ameren Illinois Company | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 166 | 133 | ||
Short-term Debt, Fair Value | 353 | 103 | ||
Long-term Debt, Fair Value | 3,868 | 4,971 | ||
Fair Value | Ameren Illinois Company | Level 1 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 166 | 133 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | 0 | 0 | ||
Fair Value | Ameren Illinois Company | Level 2 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Short-term Debt, Fair Value | 353 | 103 | ||
Long-term Debt, Fair Value | 3,868 | 4,971 | ||
Fair Value | Ameren Illinois Company | Level 3 | ||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||||
Cash, cash equivalents, and restricted cash | 0 | 0 | ||
Short-term Debt, Fair Value | 0 | 0 | ||
Long-term Debt, Fair Value | $ 0 | $ 0 |
Related Party Transactions (Nar
Related Party Transactions (Narrative) (Details) - Ameren Services Support Services Agreement - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Union Electric Company | ||
Related Party Transaction [Line Items] | ||
Due from Related Parties | $ 80 | $ 77 |
Ameren Illinois Company | ||
Related Party Transaction [Line Items] | ||
Due from Related Parties | $ 83 | $ 80 |
Related Party Transactions (Sch
Related Party Transactions (Schedule of Affiliate Receivables and Payables) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 |
Union Electric Company | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | $ 43 | $ 46 |
Accounts Receivable, Related Parties, Current | 23 | 44 |
Union Electric Company | Income taxes payable to parent | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 0 | 0 |
Union Electric Company | Income taxes receivable from parent | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | 12 | 27 |
Ameren Illinois Company | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 117 | 64 |
Accounts Receivable, Related Parties, Current | 9 | 24 |
Ameren Illinois Company | Income taxes payable to parent | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 72 | 8 |
Ameren Illinois Company | Income taxes receivable from parent | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | $ 0 | $ 18 |
Related Party Transactions (Eff
Related Party Transactions (Effects of Related-party Transactions on the Statement of Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Union Electric Company | Ameren Missouri Power Supply Agreements with Ameren Illinois | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | $ 2 | $ 5 | $ 7 | $ 10 |
Union Electric Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 6 | 6 | 18 | 20 |
Operating Expenses | 1 | 1 | 1 | 1 |
Union Electric Company | Ameren Missouri and Ameren Illinois Miscellaneous Support Services | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Union Electric Company | Total Related Party Operating Revenues | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 8 | 11 | 25 | 30 |
Union Electric Company | Ameren Missouri and Ameren Illinois Transmission Services from ATXI | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 1 | 1 | 1 | 3 |
Union Electric Company | Purchased Power | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 1 | 1 | 1 | 3 |
Union Electric Company | Ameren Services Support Services Agreement | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 38 | 41 | 109 | 110 |
Union Electric Company | Total Related Party Other Operations and Maintenance | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 38 | 41 | 109 | 110 |
Union Electric Company | Money pool borrowings (advances) | ||||
Related Party Transaction [Line Items] | ||||
Interest Charges (Income) | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Operating Expenses | 1 | 1 | 2 | 3 |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Miscellaneous Support Services | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 3 | 1 | 5 |
Ameren Illinois Company | Total Related Party Operating Revenues | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 3 | 1 | 5 |
Ameren Illinois Company | Ameren Illinois Power Supply Agreements with Ameren Missouri | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 2 | 5 | 7 | 10 |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Transmission Services from ATXI | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Purchased Power | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 2 | 5 | 7 | 11 |
Ameren Illinois Company | Ameren Services Support Services Agreement | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 36 | 37 | 103 | 101 |
Ameren Illinois Company | Total Related Party Other Operations and Maintenance | ||||
Related Party Transaction [Line Items] | ||||
Operating Expenses | 37 | 38 | 105 | 104 |
Ameren Illinois Company | Money pool borrowings (advances) | ||||
Related Party Transaction [Line Items] | ||||
Interest Charges (Income) | $ 1 | $ 1 | $ 1 | $ 1 |
Commitments And Contingencies (
Commitments And Contingencies (Environmental Matters) (Detail) $ in Millions | 9 Months Ended | |
Sep. 30, 2022 USD ($) energyCenter scrubber site | Dec. 31, 2021 USD ($) | |
Loss Contingencies [Line Items] | ||
Asset Retirement Obligation | $ 778 | $ 764 |
Minimum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 125 | |
Maximum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | $ 175 | |
Union Electric Company | ||
Loss Contingencies [Line Items] | ||
Number of Energy Center Scrubbers | scrubber | 2 | |
Number of Energy Centers Constructing Wastewater Treatment Facilities | energyCenter | 3 | |
Number of energy centers | energyCenter | 4 | |
Number of Days to Comply after Final EPA Determination | 135 days | |
Asset Retirement Obligation | $ 774 | 760 |
Number of Ameren Missouri Natural Gas Energy Centers Subject To IETL | energyCenter | 4 | |
Union Electric Company | Coal Fired Electric Generation Equipment | ||
Loss Contingencies [Line Items] | ||
Plant To Be Abandoned, Net | $ 600 | |
Union Electric Company | Minimum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 125 | |
Union Electric Company | Maximum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 175 | |
Ameren Illinois Company | ||
Loss Contingencies [Line Items] | ||
Asset Retirement Obligation | 4 | $ 4 |
Coal Combustion Residuals Estimate | Union Electric Company | Minimum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 60 | |
Coal Combustion Residuals Estimate | Union Electric Company | Maximum | ||
Loss Contingencies [Line Items] | ||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 80 | |
Manufactured Gas Plant | ||
Loss Contingencies [Line Items] | ||
Accrual for environmental loss contingencies | $ 71 | |
Manufactured Gas Plant | Ameren Illinois Company | ||
Loss Contingencies [Line Items] | ||
Number of remediation sites | site | 44 | |
Accrual for environmental loss contingencies | $ 71 | |
Manufactured Gas Plant | Ameren Illinois Company | Minimum | ||
Loss Contingencies [Line Items] | ||
Estimate of possible loss | 71 | |
Manufactured Gas Plant | Ameren Illinois Company | Maximum | ||
Loss Contingencies [Line Items] | ||
Estimate of possible loss | 145 | |
Rush Island Energy Center | Union Electric Company | ||
Loss Contingencies [Line Items] | ||
Rate Base | 500 | |
New CCR Rules Estimate | ||
Loss Contingencies [Line Items] | ||
Asset Retirement Obligation | 49 | |
New CCR Rules Estimate | Union Electric Company | ||
Loss Contingencies [Line Items] | ||
Asset Retirement Obligation | $ 49 |
Callaway Energy Center (Insuran
Callaway Energy Center (Insurance Disclosure) (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2022 USD ($) yr | |
Nuclear Waste Matters [Line Items] | |
Decommissioning Cost | $ 7 |
Frequency of Decommissioning Cost Study | 3 years |
Proceeds from Insurance Settlement, Investing Activities | $ 22 |
Number Of Years The Limit Of Liability And The Maximum Potential Annual Payments Are Adjusted | 5 years |
Number Of Weeks Of Coverage After The First Twelve Weeks Of An Outage | yr | 1 |
Number Of Additional Weeks After Initial Indemnity Coverage For Power Outage | yr | 1.365 |
Public Liability And Nuclear Worker Liability - American Nuclear Insurers | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | $ 450 |
Insurance Maximum Coverage per Incident | 0 |
Public Liability And Nuclear Worker Liability - Pool Participation | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 13,210 |
Insurance Maximum Coverage per Incident | 138 |
Threshold Amount For Retrospective Insurance Assessment For Covered Loss Under Public Liability And Nuclear Worker Liability Insurance Policy | 450 |
Maximum Annual Payment Per Incident At Licensed Commercial Nuclear Reactor | 21 |
Public Liability | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 13,660 |
Insurance Maximum Coverage per Incident | 138 |
Property Damage - Nuclear Electric Insurance Ltd | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 3,200 |
Insurance Maximum Coverage per Incident | 26 |
Accidental Outage - Nuclear Electric Insurance Ltd | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 490 |
Insurance Maximum Coverage per Incident | 7 |
Amount Of Weekly Indemnity Coverage Commencing Twelve Weeks After Power Outage | 4.5 |
Amount Of Additional Weekly Indemnity Coverage Commencing After Initial Indemnity Coverage | 3.6 |
Amount Of Weekly Indemnity Coverage Thereafter Not Exceeding Policy Limit | 490 |
Sub-Limit Of Amount Of Weekly Indemnity Coverage Thereafter Not Exceeding Policy Limit For Non-Nuclear Events | 328 |
Radiation Event | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 2,700 |
Aggregate Nuclear Power Industry Insurance Policy Limit For Losses From Terrorist Attacks Within Twelve Month Period | 3,200 |
Non-Radiation Event | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 2,300 |
Aggregate Nuclear Power Industry Insurance Policy Limit For Losses From Terrorist Attacks Within Twelve Month Period | 1,800 |
Property Damage European Mutual Association for Nuclear Insurance | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | $ 490 |
Retirement Benefits (Components
Retirement Benefits (Components Of Net Periodic Benefit Cost) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Total non-service cost components | $ (45) | $ (34) | $ (138) | $ (102) |
Pension Plan | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Service Cost | 31 | 33 | 95 | 100 |
Interest cost | 42 | 38 | 123 | 114 |
Expected return on plan assets | (80) | (74) | (240) | (223) |
Prior service benefit | 0 | 0 | 0 | 0 |
Actuarial loss (gain) | 7 | 18 | 19 | 55 |
Total non-service cost components | (31) | (18) | (98) | (54) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 0 | 15 | (3) | 46 |
Other Postretirement Benefit Plan, Defined Benefit | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Service Cost | 5 | 5 | 15 | 17 |
Interest cost | 8 | 9 | 25 | 25 |
Expected return on plan assets | (21) | (20) | (64) | (60) |
Prior service benefit | (1) | (1) | (3) | (3) |
Actuarial loss (gain) | (5) | (1) | (14) | (4) |
Total non-service cost components | (19) | (13) | (56) | (42) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | $ (14) | $ (8) | $ (41) | $ (25) |
Retirement Benefits (Summary of
Retirement Benefits (Summary of Benefit Plan Costs Incurred) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Pension Plan | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | $ 0 | $ 15 | $ (3) | $ 46 |
Pension Plan | Union Electric Company | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | 0 | 7 | (2) | 22 |
Pension Plan | Ameren Illinois Company | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | 1 | 8 | 2 | 25 |
Pension Plan | Other Affiliated Entities And Intercompany Eliminations | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | (1) | 0 | (3) | (1) |
Other Postretirement Benefit Plan, Defined Benefit | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | (14) | (8) | (41) | (25) |
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) | (10) | (3) |
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 | (11) | (8) | (31) | (23) |
Other Postretirement Benefit Plan, Defined Benefit | Other Affiliated Entities And Intercompany Eliminations | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | $ 0 | $ 1 | $ 0 | $ 1 |
Income Taxes (Schedule of Effec
Income Taxes (Schedule of Effective Income Tax Rate Reconciliation) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | Aug. 16, 2022 | |
Income Taxes [Line Items] | |||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% | |
Increases (decreases) from: | |||||
Amortization of deferred investment tax credit | 0% | (1.00%) | 0% | 0% | |
Amortization of excess deferred taxes | (8.00%) | (8.00%) | (8.00%) | (9.00%) | |
Depreciation differences | 0% | 0% | |||
Renewable and other tax credits | (4.00%) | (2.00%) | (4.00%) | (3.00%) | |
State tax | 4% | 4% | 5% | 5% | |
Stock-based compensation | 1% | 0% | 0% | (1.00%) | |
Cash surrender value of COLI | 1% | 0% | |||
Effective income tax rate | 15% | 14% | 14% | 13% | |
Production and Investment Tax Credit Adder | 10% | ||||
Greenhouse Emissions Reduction Target, Inflation Reduction Act | 75% | ||||
Tax Credit Transferability, Inflation Reduction Act, Percent | 100% | ||||
Minimum Tax on Book Income, Percent | 15% | ||||
Minimum Adjusted Financial Statement Income Subject to Inflation Reduction Act Tax | $ 1,000 | ||||
Union Electric Company | |||||
Income Taxes [Line Items] | |||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% | |
Increases (decreases) from: | |||||
Amortization of deferred investment tax credit | (1.00%) | (1.00%) | (1.00%) | 0% | |
Amortization of excess deferred taxes | (15.00%) | (17.00%) | (15.00%) | (17.00%) | |
Depreciation differences | 0% | 0% | |||
Renewable and other tax credits | (10.00%) | (8.00%) | (10.00%) | (8.00%) | |
State tax | 3% | 4% | 3% | 3% | |
Stock-based compensation | 0% | 0% | 0% | 0% | |
Cash surrender value of COLI | 0% | 0% | |||
Effective income tax rate | (2.00%) | (1.00%) | (2.00%) | (1.00%) | |
Ameren Illinois Company | |||||
Income Taxes [Line Items] | |||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% | |
Increases (decreases) from: | |||||
Amortization of deferred investment tax credit | 0% | 0% | 0% | 0% | |
Amortization of excess deferred taxes | (2.00%) | (2.00%) | (2.00%) | (3.00%) | |
Depreciation differences | 0% | (1.00%) | |||
Renewable and other tax credits | 0% | 0% | 0% | 0% | |
State tax | 7% | 7% | 7% | 7% | |
Stock-based compensation | 0% | 0% | 0% | 0% | |
Cash surrender value of COLI | 0% | 0% | |||
Effective income tax rate | 26% | 25% | 26% | 25% |
Supplemental Information (Cash
Supplemental Information (Cash and Cash Equivalents) (Details) - USD ($) $ in Millions | Sep. 30, 2022 | Dec. 31, 2021 | Sep. 30, 2021 | Dec. 31, 2020 |
Schedule of Cash and Cash Equivalents Including Restricted Cash [Line Items] | ||||
Cash and cash equivalents | $ 7 | $ 8 | ||
Restricted cash included in “Other current assets” | 7 | 16 | ||
Restricted cash included in “Other assets” | 162 | 127 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 4 | 4 | ||
Total cash, cash equivalents, and restricted cash | 180 | 155 | $ 145 | $ 301 |
Union Electric Company | ||||
Schedule of Cash and Cash Equivalents Including Restricted Cash [Line Items] | ||||
Cash and cash equivalents | 0 | 0 | ||
Restricted cash included in “Other current assets” | 3 | 4 | ||
Restricted cash included in “Other assets” | 0 | 0 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 4 | 4 | ||
Total cash, cash equivalents, and restricted cash | 7 | 8 | 11 | 145 |
Ameren Illinois Company | ||||
Schedule of Cash and Cash Equivalents Including Restricted Cash [Line Items] | ||||
Cash and cash equivalents | 0 | 0 | ||
Restricted cash included in “Other current assets” | 4 | 6 | ||
Restricted cash included in “Other assets” | 162 | 127 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 0 | 0 | ||
Total cash, cash equivalents, and restricted cash | $ 166 | $ 133 | $ 122 | $ 147 |
Supplemental Information (Allow
Supplemental Information (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | Dec. 31, 2021 | |
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | $ 30 | $ 42 | $ 29 | $ 50 | |
Bad debt expense | 15 | 7 | 26 | 8 | |
Net write-offs | (14) | (13) | (24) | (22) | |
End of period | 31 | $ 36 | 31 | $ 36 | |
Payables for purchased receivables | $ 32 | $ 32 | $ 27 | ||
Percentage of accounts receivable balances that are 30 days past due or are part of a deferred payment arrangement | 17% | 18% | 17% | 18% | |
Accounts receivable balances that are 30 days or more past due or part of a deferred payment arrangement | $ 117 | $ 97 | $ 117 | $ 97 | |
Union Electric Company | |||||
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | 12 | 16 | 13 | 16 | |
Bad debt expense | 3 | 2 | 6 | 5 | |
Net write-offs | (3) | (4) | (7) | (7) | |
End of period | $ 12 | $ 14 | $ 12 | $ 14 | |
Percentage of accounts receivable balances that are 30 days past due or are part of a deferred payment arrangement | 12% | 12% | 12% | 12% | |
Accounts receivable balances that are 30 days or more past due or part of a deferred payment arrangement | $ 39 | $ 33 | $ 39 | $ 33 | |
Ameren Illinois Company | |||||
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | 18 | 26 | 16 | 34 | |
Bad debt expense | 12 | 5 | 20 | 3 | |
Net write-offs | (11) | (9) | (17) | (15) | |
End of period | 19 | $ 22 | 19 | $ 22 | |
Payables for purchased receivables | $ 32 | $ 32 | $ 27 | ||
Percentage of accounts receivable balances that are 30 days past due or are part of a deferred payment arrangement | 21% | 25% | 21% | 25% | |
Accounts receivable balances that are 30 days or more past due or part of a deferred payment arrangement | $ 78 | $ 64 | $ 78 | $ 64 |
Supplemental Information (Suppl
Supplemental Information (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |
Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Supplemental Cash Flow Information [Line Items] | |||
Wind generation expenditures | $ 98 | $ 515 | |
Accrued capital expenditures | $ 367 | 396 | |
Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund | (262) | 85 | |
Issuance of common stock for stock-based compensation | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | 31 | 33 | |
Issuance of common stock under the DRPlus | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | 8 | 0 | |
Union Electric Company | |||
Supplemental Cash Flow Information [Line Items] | |||
Wind generation expenditures | $ 98 | 515 | |
Accrued capital expenditures | 187 | 209 | |
Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund | (262) | 85 | |
Union Electric Company | Issuance of common stock for stock-based compensation | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | 0 | 0 | |
Union Electric Company | Issuance of common stock under the DRPlus | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | 0 | 0 | |
Ameren Illinois Company | |||
Supplemental Cash Flow Information [Line Items] | |||
Accrued capital expenditures | 180 | 182 | |
Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund | 0 | 0 | |
Ameren Illinois Company | Issuance of common stock for stock-based compensation | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | 0 | 0 | |
Ameren Illinois Company | Issuance of common stock under the DRPlus | |||
Supplemental Cash Flow Information [Line Items] | |||
Stock Issued | $ 0 | $ 0 |
Supplemental Information (Sched
Supplemental Information (Schedule of Asset Retirement Obligations) (Details) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2022 | Dec. 31, 2021 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | $ 764 | |
Liabilities incurred | 1 | |
Liabilities settled | (3) | |
Accretion | 23 | |
Change in estimates | (7) | |
Asset Retirement Obligation, Ending Balance | 778 | |
Other current liabilities | 584 | $ 494 |
Union Electric Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | 760 | |
Liabilities incurred | 1 | |
Liabilities settled | (3) | |
Accretion | 23 | |
Change in estimates | (7) | |
Asset Retirement Obligation, Ending Balance | 774 | |
Other current liabilities | 114 | 116 |
Ameren Illinois Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | 4 | |
Liabilities incurred | 0 | |
Liabilities settled | 0 | |
Accretion | 0 | |
Change in estimates | 0 | |
Asset Retirement Obligation, Ending Balance | 4 | |
Other current liabilities | 275 | 251 |
Asset Retirement Obligation Balance | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Other current liabilities | 7 | 7 |
Asset Retirement Obligation Balance | Union Electric Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Other current liabilities | $ 7 | $ 7 |
Supplemental Information (Narra
Supplemental Information (Narrative) (Details) - USD ($) $ in Millions | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Dec. 31, 2021 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Number of Shares Available for Grant | 8,800,000 | ||
Effective Income Tax Rate Reconciliation, Share-based Compensation, Excess Tax Benefit, Amount | $ 5 | $ 5 | |
Deferred Compensation Liability, Classified, Noncurrent | $ 88 | $ 91 | |
Q1 2022 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period | 3 years | ||
Performance Shares | Q1 2022 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 267,849 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Granted in Period, Fair Value | $ 25 | ||
Stock Issued During Period Percentage Conversion Of Units, Low End | 0% | ||
Stock Issued During Period Percentage Conversion Of Units, High End | 200% | ||
Performance Shares | Market performance measures achievement | Q1 2022 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 229,566 | ||
Performance Shares | Renewable generation and energy storage installation targets | Q1 2022 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 38,283 | ||
Restricted Stock Units (RSUs) | Q1 2022 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 122,882 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Granted in Period, Fair Value | $ 11 |
Supplemental Information (Sch_2
Supplemental Information (Schedule Of Excise Taxes) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 83 | $ 81 | $ 229 | $ 213 |
Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | 55 | 54 | 128 | 120 |
Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 28 | $ 27 | $ 101 | $ 93 |
Supplemental Information (Earni
Supplemental Information (Earnings Per Share) (Details) - shares | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Earnings Per Share Reconciliation [Abstract] | ||||
Weighted-average Common Shares Outstanding – Basic | 258,400,000 | 257,300,000 | 258,200,000 | 255,900,000 |
Assumed settlement of performance share units and restricted stock units | 900,000 | 1,300,000 | 1,000,000 | 1,300,000 |
Dilutive effect of forward sale agreements | 200,000 | 0 | 100,000 | 0 |
Weighted-average Common Shares Outstanding – Diluted | 259,500,000 | 258,600,000 | 259,300,000 | 257,200,000 |
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount (in shares) | 0 | 0 | 0 | 0 |
Segment Information (Schedule O
Segment Information (Schedule Of Segment Reporting Information By Segment) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Segment Reporting Information [Line Items] | ||||
Revenues | $ 2,306 | $ 1,811 | $ 5,911 | $ 4,849 |
Net income (loss) attributable to common shareholders | 452 | 425 | 911 | 865 |
Capital expenditures | 899 | 850 | 2,437 | 2,613 |
Wind generation expenditures | 98 | 515 | ||
Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,359 | 1,129 | 3,096 | 2,642 |
Net income (loss) attributable to common shareholders | 397 | 375 | 547 | 533 |
Wind generation expenditures | 98 | 515 | ||
Ameren Illinois Company | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 904 | 645 | 2,697 | 2,097 |
Net income (loss) attributable to common shareholders | 103 | 79 | 375 | 314 |
Capital expenditures | 446 | 380 | 1,145 | 1,026 |
Operating Segments | Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,351 | 1,118 | 3,071 | 2,612 |
Net income (loss) attributable to common shareholders | 397 | 375 | 547 | 533 |
Capital expenditures | 431 | 466 | 1,237 | 1,567 |
Operating Segments | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 672 | 425 | 1,640 | 1,222 |
Net income (loss) attributable to common shareholders | 51 | 36 | 151 | 123 |
Capital expenditures | 163 | 143 | 444 | 429 |
Operating Segments | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Net income (loss) attributable to common shareholders | (4) | (8) | 82 | 75 |
Capital expenditures | 114 | 93 | 232 | 202 |
Operating Segments | Ameren Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 137 | 141 | 389 | 373 |
Net income (loss) attributable to common shareholders | 78 | 73 | 199 | 175 |
Capital expenditures | 187 | 154 | 519 | 426 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 672 | 428 | 1,641 | 1,227 |
Net income (loss) attributable to common shareholders | 51 | 36 | 151 | 123 |
Capital expenditures | 163 | 143 | 444 | 429 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Net income (loss) attributable to common shareholders | (4) | (8) | 82 | 75 |
Capital expenditures | 114 | 93 | 232 | 202 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 86 | 90 | 245 | 228 |
Net income (loss) attributable to common shareholders | 56 | 51 | 142 | 116 |
Capital expenditures | 169 | 144 | 469 | 395 |
Other | ||||
Segment Reporting Information [Line Items] | ||||
Net income (loss) attributable to common shareholders | (70) | (51) | (68) | (41) |
Capital expenditures | 1 | 2 | 4 | 3 |
Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (40) | (33) | (102) | (88) |
Capital expenditures | 3 | (8) | 1 | (14) |
Intersegment Eliminations | Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (8) | (11) | (25) | (30) |
Intersegment Eliminations | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | 0 | (3) | (1) | (5) |
Intersegment Eliminations | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (32) | (19) | (76) | (53) |
Intersegment Eliminations | Ameren Illinois Company | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (31) | (18) | (75) | (49) |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | $ (31) | $ (18) | $ (75) | $ (49) |
Segment Information (Disaggrega
Segment Information (Disaggregation of Revenue) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2022 | Sep. 30, 2021 | Sep. 30, 2022 | Sep. 30, 2021 | |
Disaggregation of Revenue [Line Items] | ||||
Revenues | $ 2,306 | $ 1,811 | $ 5,911 | $ 4,849 |
Revenues | 2,306 | 1,811 | 5,911 | 4,849 |
Revenues from alternative revenue programs | (83) | (95) | 2 | (6) |
Other revenues not from contracts with customers | (43) | 13 | (74) | 82 |
Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 14 | 6 | 8 | (9) |
Other revenues not from contracts with customers | (45) | 7 | (81) | 71 |
Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (83) | (97) | 13 | (2) |
Other revenues not from contracts with customers | 2 | 6 | 5 | 9 |
Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (3) | (5) | (5) | 0 |
Other revenues not from contracts with customers | 0 | 0 | 2 | 2 |
Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (11) | 1 | (14) | 5 |
Other revenues not from contracts with customers | 0 | 0 | 0 | 0 |
Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 2,140 | 1,668 | 4,971 | 4,108 |
Revenues | 2,140 | 1,668 | 4,971 | 4,108 |
Electric | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 971 | 795 | 2,221 | 1,882 |
Electric | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 663 | 555 | 1,539 | 1,301 |
Electric | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 124 | 374 | 315 |
Electric | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 360 | 194 | 837 | 610 |
Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 166 | 143 | 940 | 741 |
Revenues | 166 | 143 | 940 | 741 |
Natural gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 100 | 84 | 653 | 492 |
Natural gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 31 | 27 | 188 | 139 |
Natural gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 6 | 3 | 37 | 22 |
Natural gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 29 | 29 | 62 | 88 |
Ameren Illinois Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 904 | 645 | 2,697 | 2,097 |
Revenues | 904 | 645 | 2,697 | 2,097 |
Revenues from alternative revenue programs | (96) | (99) | (4) | 2 |
Other revenues not from contracts with customers | 2 | 6 | 7 | 11 |
Ameren Illinois Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 496 | 333 | 1,529 | 1,143 |
Ameren Illinois Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 258 | 166 | 723 | 518 |
Ameren Illinois Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 52 | 29 | 178 | 114 |
Ameren Illinois Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 98 | 117 | 267 | 322 |
Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (83) | (97) | 13 | (2) |
Other revenues not from contracts with customers | 2 | 6 | 5 | 9 |
Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (3) | (5) | (5) | 0 |
Other revenues not from contracts with customers | 0 | 0 | 2 | 2 |
Ameren Illinois Company | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (10) | 3 | (12) | 4 |
Other revenues not from contracts with customers | 0 | 0 | 0 | 0 |
Ameren Illinois Company | Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 758 | 518 | 1,886 | 1,455 |
Ameren Illinois Company | Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Operating Segments | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 1,351 | 1,118 | 3,071 | 2,612 |
Revenues | 1,359 | 1,129 | 3,096 | 2,642 |
Operating Segments | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 672 | 425 | 1,640 | 1,222 |
Revenues | 672 | 428 | 1,641 | 1,227 |
Operating Segments | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Revenues | 146 | 127 | 811 | 642 |
Operating Segments | Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 137 | 141 | 389 | 373 |
Revenues | 169 | 160 | 465 | 426 |
Operating Segments | Electric | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 1,338 | 1,113 | 2,966 | 2,543 |
Operating Segments | Electric | Union Electric Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 564 | 537 | 1,267 | 1,177 |
Operating Segments | Electric | Union Electric Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 430 | 412 | 968 | 899 |
Operating Segments | Electric | Union Electric Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 99 | 98 | 229 | 221 |
Operating Segments | Electric | Union Electric Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 245 | 66 | 502 | 246 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 672 | 428 | 1,641 | 1,227 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 407 | 258 | 954 | 705 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 233 | 143 | 571 | 402 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 47 | 26 | 145 | 94 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (15) | 1 | (29) | 26 |
Operating Segments | Electric | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 169 | 160 | 465 | 426 |
Operating Segments | Electric | Ameren Transmission | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 169 | 160 | 465 | 426 |
Operating Segments | Natural gas | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 21 | 16 | 130 | 99 |
Operating Segments | Natural gas | Union Electric Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 11 | 9 | 78 | 54 |
Operating Segments | Natural gas | Union Electric Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 6 | 4 | 36 | 23 |
Operating Segments | Natural gas | Union Electric Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 1 | 0 | 4 | 2 |
Operating Segments | Natural gas | Union Electric Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 3 | 3 | 12 | 20 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 89 | 75 | 575 | 438 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 25 | 23 | 152 | 116 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 5 | 3 | 33 | 20 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 27 | 26 | 51 | 68 |
Operating Segments | Natural gas | Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 672 | 428 | 1,641 | 1,227 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 86 | 90 | 245 | 228 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 672 | 428 | 1,641 | 1,227 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 407 | 258 | 954 | 705 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 233 | 143 | 571 | 402 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 47 | 26 | 145 | 94 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (15) | 1 | (29) | 26 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 117 | 108 | 320 | 277 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 117 | 108 | 320 | 277 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 146 | 127 | 811 | 642 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 89 | 75 | 575 | 438 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 25 | 23 | 152 | 116 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 5 | 3 | 33 | 20 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 27 | 26 | 51 | 68 |
Intersegment Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (40) | (33) | (102) | (88) |
Revenues | (40) | (33) | (102) | (88) |
Intersegment Eliminations | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (8) | (11) | (25) | (30) |
Intersegment Eliminations | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | (3) | (1) | (5) |
Intersegment Eliminations | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (32) | (19) | (76) | (53) |
Intersegment Eliminations | Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (39) | (33) | (101) | (88) |
Intersegment Eliminations | Electric | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (39) | (33) | (101) | (88) |
Intersegment Eliminations | Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (1) | 0 | (1) | 0 |
Intersegment Eliminations | Natural gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (1) | 0 | (1) | 0 |
Intersegment Eliminations | Ameren Illinois Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (31) | (18) | (75) | (49) |
Revenues | (31) | (18) | (75) | (49) |
Intersegment Eliminations | Ameren Illinois Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (31) | (18) | (75) | (49) |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | $ (31) | $ (18) | $ (75) | $ (49) |