Cover Page
Cover Page - shares | 6 Months Ended | |
Jun. 30, 2024 | Jul. 31, 2024 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Jun. 30, 2024 | |
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 | 266,816,725 | |
Entity Central Index Key | 0001002910 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2024 | |
Document Fiscal Period Focus | Q2 | |
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 | 2024 | |
Document Fiscal Period Focus | Q2 | |
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 | 2024 | |
Document Fiscal Period Focus | Q2 | |
Amendment Flag | false |
Consolidated Statement of Incom
Consolidated Statement of Income (Loss) and Comprehensive Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Operating Revenues: | ||||
Total operating revenues | $ 1,693 | $ 1,760 | $ 3,509 | $ 3,822 |
Operating Expenses: | ||||
Fuel and purchased power | 327 | 480 | 655 | 1,088 |
Natural gas purchased for resale | 33 | 42 | 184 | 250 |
Other operations and maintenance | 465 | 450 | 935 | 898 |
Depreciation and amortization | 376 | 335 | 737 | 655 |
Taxes other than income taxes | 131 | 124 | 266 | 251 |
Total operating expenses | 1,332 | 1,431 | 2,777 | 3,142 |
Operating Income | 361 | 329 | 732 | 680 |
Other Income, Net | 103 | 82 | 192 | 160 |
Interest Charges | 165 | 134 | 319 | 261 |
Income Before Income Taxes | 299 | 277 | 605 | 579 |
Income Taxes | 39 | 38 | 83 | 75 |
Net Income | 260 | 239 | 522 | 504 |
Less: Net Income Attributable to Noncontrolling Interests | 2 | 2 | 3 | 3 |
Net Income Attributable to Ameren Common Shareholders | 258 | 237 | 519 | 501 |
Pension and other postretirement benefit plan activity, net of income taxes (benefit) | (2) | (1) | (3) | (2) |
Comprehensive Income | 258 | 238 | 519 | 502 |
Less: Comprehensive Income Attributable to Noncontrolling Interests | 2 | 2 | 3 | 3 |
Comprehensive Income Attributable to Ameren Common Shareholders | $ 256 | $ 236 | $ 516 | $ 499 |
Earnings Per Share, Basic [Abstract] | ||||
Earnings per Common Share – Basic | $ 0.97 | $ 0.90 | $ 1.95 | $ 1.91 |
Earnings Per Share, Diluted [Abstract] | ||||
Earnings per Common Share – Diluted | $ 0.97 | $ 0.90 | $ 1.95 | $ 1.90 |
Weighted-average Common Shares Outstanding – Basic | 266.7 | 262.6 | 266.5 | 262.4 |
Weighted-average Common Shares Outstanding – Diluted | 266.8 | 263.2 | 266.8 | 263.2 |
Electric | ||||
Operating Revenues: | ||||
Total operating revenues | $ 1,521 | $ 1,585 | $ 2,885 | $ 3,175 |
Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 172 | 175 | 624 | 647 |
Union Electric Company | ||||
Operating Revenues: | ||||
Total operating revenues | 888 | 941 | 1,663 | 1,864 |
Operating Expenses: | ||||
Fuel and purchased power | 189 | 289 | 355 | 610 |
Natural gas purchased for resale | 9 | 9 | 37 | 56 |
Other operations and maintenance | 247 | 237 | 501 | 476 |
Depreciation and amortization | 208 | 186 | 403 | 362 |
Taxes other than income taxes | 91 | 88 | 178 | 168 |
Total operating expenses | 744 | 809 | 1,474 | 1,672 |
Operating Income | 144 | 132 | 189 | 192 |
Other Income, Net | 49 | 22 | 93 | 41 |
Interest Charges | 63 | 52 | 125 | 103 |
Income Before Income Taxes | 130 | 102 | 157 | 130 |
Income Taxes | 1 | (1) | 2 | (2) |
Net Income | 129 | 103 | 155 | 132 |
Preferred Stock Dividends | 1 | 1 | 2 | 2 |
Net Income Attributable to Parent | 128 | 102 | 153 | 130 |
Union Electric Company | Electric | ||||
Operating Revenues: | ||||
Total operating revenues | 864 | 918 | 1,578 | 1,759 |
Union Electric Company | Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | 24 | 23 | 85 | 105 |
Ameren Illinois Company | ||||
Operating Revenues: | ||||
Total operating revenues | 766 | 779 | 1,766 | 1,880 |
Operating Expenses: | ||||
Purchased Power | 141 | 192 | 305 | 479 |
Natural gas purchased for resale | 24 | 33 | 147 | 194 |
Other operations and maintenance | 224 | 201 | 434 | 403 |
Depreciation and amortization | 154 | 138 | 307 | 271 |
Taxes other than income taxes | 35 | 32 | 79 | 74 |
Total operating expenses | 578 | 596 | 1,272 | 1,421 |
Operating Income | 188 | 183 | 494 | 459 |
Other Income, Net | 37 | 41 | 68 | 78 |
Interest Charges | 60 | 50 | 115 | 97 |
Income Before Income Taxes | 165 | 174 | 447 | 440 |
Income Taxes | 40 | 44 | 107 | 112 |
Net Income | 125 | 130 | 340 | 328 |
Preferred Stock Dividends | 1 | 1 | 1 | 1 |
Net Income Attributable to Parent | 124 | 129 | 339 | 327 |
Ameren Illinois Company | Electric | ||||
Operating Revenues: | ||||
Total operating revenues | 618 | 627 | 1,227 | 1,337 |
Ameren Illinois Company | Natural gas | ||||
Operating Revenues: | ||||
Total operating revenues | $ 148 | $ 152 | $ 539 | $ 543 |
Consolidated Statement of Inc_2
Consolidated Statement of Income (Loss) and Comprehensive Income (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Income Statement [Abstract] | ||||
Pension and other postretirement benefit plan activity, tax | $ (1) | $ 0 | $ (1) | $ 0 |
Consolidated Balance Sheet
Consolidated Balance Sheet - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Current Assets: | ||
Cash and cash equivalents | $ 19 | $ 25 |
Accounts receivable - trade (less allowance for doubtful accounts) | 514 | 494 |
Unbilled revenue | 407 | 319 |
Miscellaneous accounts receivable | 62 | 106 |
Inventories | 740 | 733 |
Current regulatory assets | 345 | 365 |
Other current assets | 130 | 139 |
Total current assets | 2,217 | 2,181 |
Property, Plant, and Equipment, Net | 34,873 | 33,776 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 1,266 | 1,150 |
Goodwill | 411 | 411 |
Regulatory assets | 1,952 | 1,810 |
Pension and other postretirement benefits | 566 | 581 |
Other assets | 1,049 | 921 |
Total investments and other assets | 5,244 | 4,873 |
TOTAL ASSETS | 42,334 | 40,830 |
Current Liabilities: | ||
Current maturities of long-term debt | 799 | 849 |
Short-term debt | 691 | 536 |
Accounts and wages payable | 774 | 1,136 |
Interest accrued | 177 | 147 |
Customer deposits | 197 | 176 |
Other current liabilities | 655 | 501 |
Total current liabilities | 3,293 | 3,345 |
Long-term Debt, Net | 16,280 | 15,121 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 4,325 | 4,176 |
Regulatory liabilities | 5,531 | 5,512 |
Asset retirement obligations | 791 | 772 |
Other deferred credits and liabilities | 446 | 426 |
Total deferred credits and other liabilities | 11,093 | 10,886 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 3 | 3 |
Other paid-in capital, principally premium on common stock | 7,246 | 7,216 |
Retained earnings | 4,299 | 4,136 |
Accumulated other comprehensive loss | (9) | (6) |
Total shareholders’ equity | 11,539 | 11,349 |
Noncontrolling Interests | 129 | 129 |
Total equity | 11,668 | 11,478 |
TOTAL LIABILITIES AND EQUITY | 42,334 | 40,830 |
Union Electric Company | ||
Current Assets: | ||
Cash and cash equivalents | 0 | 0 |
Unbilled revenue | 271 | 163 |
Miscellaneous accounts receivable | 30 | 26 |
Inventories | 520 | 508 |
Current regulatory assets | 124 | 101 |
Other current assets | 63 | 68 |
Total current assets | 1,286 | 1,142 |
Property, Plant, and Equipment, Net | 17,938 | 17,250 |
Investments and Other Assets: | ||
Nuclear decommissioning trust fund | 1,266 | 1,150 |
Regulatory assets | 733 | 755 |
Pension and other postretirement benefits | 138 | 157 |
Other assets | 194 | 152 |
Total investments and other assets | 2,331 | 2,214 |
TOTAL ASSETS | 21,555 | 20,606 |
Current Liabilities: | ||
Current maturities of long-term debt | 0 | 350 |
Short-term debt | 390 | 170 |
Borrowings from money pool | 0 | 306 |
Interest accrued | 82 | 69 |
Taxes accrued | 132 | 28 |
Other current liabilities | 234 | 153 |
Total current liabilities | 1,262 | 1,747 |
Long-term Debt, Net | 6,830 | 5,991 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 2,196 | 2,122 |
Regulatory liabilities | 2,925 | 2,959 |
Asset retirement obligations | 788 | 768 |
Other deferred credits and liabilities | 88 | 56 |
Total deferred credits and other liabilities | 5,997 | 5,905 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 511 | 511 |
Other paid-in capital, principally premium on common stock | 3,075 | 2,725 |
Preferred stock | 80 | 80 |
Retained earnings | 3,800 | 3,647 |
Total shareholders’ equity | 7,466 | 6,963 |
TOTAL LIABILITIES AND EQUITY | 21,555 | 20,606 |
Union Electric Company | Nonrelated Party | ||
Current Assets: | ||
Accounts receivable - trade (less allowance for doubtful accounts) | 211 | 204 |
Current Liabilities: | ||
Accounts and wages payable | 366 | 618 |
Union Electric Company | Related Party | ||
Current Assets: | ||
Accounts receivable - trade (less allowance for doubtful accounts) | 67 | 72 |
Current Liabilities: | ||
Accounts and wages payable | 58 | 53 |
Ameren Illinois Company | ||
Current Assets: | ||
Cash and cash equivalents | 6 | 0 |
Advances to money pool | 30 | 0 |
Unbilled revenue | 136 | 156 |
Miscellaneous accounts receivable | 5 | 44 |
Inventories | 216 | 225 |
Current regulatory assets | 215 | 252 |
Other current assets | 55 | 62 |
Total current assets | 961 | 1,047 |
Property, Plant, and Equipment, Net | 15,009 | 14,632 |
Investments and Other Assets: | ||
Goodwill | 411 | 411 |
Regulatory assets | 1,189 | 1,035 |
Pension and other postretirement benefits | 412 | 394 |
Other assets | 656 | 603 |
Total investments and other assets | 2,668 | 2,443 |
TOTAL ASSETS | 18,638 | 18,122 |
Current Liabilities: | ||
Current maturities of long-term debt | 300 | 0 |
Short-term debt | 0 | 366 |
Borrowings from money pool | 0 | 135 |
Customer deposits | 161 | 141 |
Zero emission credit liabilities | 64 | 35 |
Current regulatory liabilities | 58 | 71 |
Other current liabilities | 219 | 263 |
Total current liabilities | 1,196 | 1,433 |
Long-term Debt, Net | 5,551 | 5,232 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes and tax credits, net | 1,967 | 1,906 |
Regulatory liabilities | 2,466 | 2,418 |
Other deferred credits and liabilities | 319 | 308 |
Total deferred credits and other liabilities | 4,752 | 4,632 |
Commitments and Contingencies | ||
Shareholders’ Equity: | ||
Common Stock | 0 | 0 |
Other paid-in capital, principally premium on common stock | 3,020 | 3,020 |
Preferred stock | 49 | 49 |
Retained earnings | 4,070 | 3,756 |
Total shareholders’ equity | 7,139 | 6,825 |
TOTAL LIABILITIES AND EQUITY | 18,638 | 18,122 |
Ameren Illinois Company | Nonrelated Party | ||
Current Assets: | ||
Accounts receivable - trade (less allowance for doubtful accounts) | 287 | 273 |
Current Liabilities: | ||
Accounts and wages payable | 297 | 370 |
Ameren Illinois Company | Related Party | ||
Current Assets: | ||
Accounts receivable - trade (less allowance for doubtful accounts) | 11 | 35 |
Current Liabilities: | ||
Accounts and wages payable | $ 97 | $ 52 |
Consolidated Balance Sheet (Par
Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Accounts Receivable, Allowance for Credit Loss, Current | $ 37 | $ 30 |
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 | 266,800,000 | 266,300,000 |
Union Electric Company | ||
Accounts Receivable, Allowance for Credit Loss, Current | $ 12 | $ 12 |
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 | $ 25 | $ 18 |
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 | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Cash Flows From Operating Activities: | ||
Net income | $ 522 | $ 504 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 760 | 703 |
Amortization of nuclear fuel | 38 | 36 |
Amortization of debt issuance costs and premium/discounts | 9 | 8 |
Deferred income taxes and investment tax credits, net | 76 | 66 |
Allowance for equity funds used during construction | (25) | (23) |
Stock-based compensation costs | 14 | 14 |
Other | 13 | (19) |
Changes in assets and liabilities: | ||
Receivables | (85) | 173 |
Inventories | (7) | (44) |
Accounts and wages payable | (210) | (335) |
Taxes accrued | 121 | 93 |
Regulatory assets and liabilities | (105) | (81) |
Assets, other | (53) | (38) |
Liabilities, other | 100 | 34 |
Pension and other postretirement benefits | (112) | (114) |
Counterparty collateral, net | (7) | 134 |
Net cash provided by operating activities | 1,049 | 1,111 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (1,892) | (1,822) |
Nuclear fuel expenditures | (37) | (50) |
Purchases of securities – nuclear decommissioning trust fund | (323) | (81) |
Sales and maturities of securities – nuclear decommissioning trust fund | 309 | 65 |
Other | 11 | (1) |
Net cash used in investing activities | (1,932) | (1,889) |
Cash Flows From Financing Activities: | ||
Dividends on common stock | (356) | (330) |
Dividends paid to noncontrolling interest holders | (3) | (3) |
Short-term debt, net | 156 | 260 |
Maturities of long-term debt | (350) | (100) |
Issuances of long-term debt | 1,470 | 997 |
Issuances of common stock | 21 | 16 |
Employee payroll taxes related to stock-based compensation | (8) | (20) |
Debt issuance costs | (18) | (9) |
Other | 0 | (3) |
Net cash provided by financing activities | 912 | 808 |
Net change in cash, cash equivalents, and restricted cash | 29 | 30 |
Cash, cash equivalents, and restricted cash at beginning of year | 272 | 216 |
Cash, cash equivalents, and restricted cash at end of period | 301 | 246 |
Union Electric Company | ||
Cash Flows From Operating Activities: | ||
Net income | 155 | 132 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 426 | 410 |
Amortization of nuclear fuel | 38 | 36 |
Amortization of debt issuance costs and premium/discounts | 3 | 3 |
Deferred income taxes and investment tax credits, net | 38 | 10 |
Allowance for equity funds used during construction | (23) | (12) |
Other | 22 | (20) |
Changes in assets and liabilities: | ||
Receivables | (121) | (9) |
Inventories | (12) | (81) |
Accounts and wages payable | (196) | (231) |
Taxes accrued | 118 | 103 |
Regulatory assets and liabilities | (31) | 28 |
Assets, other | (30) | 13 |
Liabilities, other | 63 | 21 |
Pension and other postretirement benefits | (40) | (41) |
Counterparty collateral, net | (3) | 81 |
Net cash provided by operating activities | 407 | 443 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (1,104) | (914) |
Nuclear fuel expenditures | (37) | (50) |
Purchases of securities – nuclear decommissioning trust fund | (323) | (81) |
Sales and maturities of securities – nuclear decommissioning trust fund | 309 | 65 |
Net cash used in investing activities | (1,155) | (980) |
Cash Flows From Financing Activities: | ||
Dividends on preferred stock | (2) | (2) |
Short-term debt, net | 220 | 44 |
Money pool borrowings, net | (306) | 0 |
Maturities of long-term debt | (350) | 0 |
Issuances of long-term debt | 846 | 499 |
Capital contributions from parent | 350 | 0 |
Debt issuance costs | (9) | (6) |
Other | 0 | (3) |
Net cash provided by financing activities | 749 | 532 |
Net change in cash, cash equivalents, and restricted cash | 1 | (5) |
Cash, cash equivalents, and restricted cash at beginning of year | 10 | 13 |
Cash, cash equivalents, and restricted cash at end of period | 11 | 8 |
Ameren Illinois Company | ||
Cash Flows From Operating Activities: | ||
Net income | 340 | 328 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 307 | 271 |
Amortization of debt issuance costs and premium/discounts | 2 | 2 |
Deferred income taxes and investment tax credits, net | 37 | 70 |
Allowance for equity funds used during construction | (2) | (10) |
Other | 8 | 12 |
Changes in assets and liabilities: | ||
Receivables | 27 | 182 |
Inventories | 9 | 37 |
Accounts and wages payable | 7 | (92) |
Taxes accrued | 55 | (36) |
Regulatory assets and liabilities | (70) | (105) |
Assets, other | (23) | (42) |
Liabilities, other | 32 | 13 |
Pension and other postretirement benefits | (43) | (46) |
Counterparty collateral, net | 5 | 53 |
Net cash provided by operating activities | 691 | 637 |
Cash Flows From Investing Activities: | ||
Capital expenditures | (717) | (844) |
Money pool advances, net | (30) | 0 |
Other | 5 | (2) |
Net cash used in investing activities | (742) | (846) |
Cash Flows From Financing Activities: | ||
Dividends on common stock | (25) | 0 |
Dividends on preferred stock | (1) | (1) |
Short-term debt, net | (366) | (147) |
Money pool borrowings, net | (135) | 0 |
Maturities of long-term debt | 0 | (100) |
Issuances of long-term debt | 624 | 498 |
Debt issuance costs | (7) | (3) |
Net cash provided by financing activities | 90 | 247 |
Net change in cash, cash equivalents, and restricted cash | 39 | 38 |
Cash, cash equivalents, and restricted cash at beginning of year | 234 | 191 |
Cash, cash equivalents, and restricted cash at end of period | $ 273 | $ 229 |
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 Loss: | Total 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, 2022 | $ 6,860 | $ 3,646 | $ (1) | $ 129 | $ 2,725 | $ 3,111 | $ 3,190 | |||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 23 | |||||||||||||||||
Stock-based compensation activity | (3) | |||||||||||||||||
Net income | $ 504 | $ 132 | 132 | $ 328 | 328 | |||||||||||||
Net income attributable to Ameren common shareholders | 501 | 501 | ||||||||||||||||
Dividends on common stock | (330) | 0 | ||||||||||||||||
Preferred stock dividends | (2) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | (2) | (2) | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (3) | 3 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (3) | |||||||||||||||||
Common stock shares outstanding at beginning of period at Dec. 31, 2022 | 262,000,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 200,000 | |||||||||||||||||
Shares issued for stock-based compensation | 500,000 | |||||||||||||||||
Common stock shares outstanding at end of period at Jun. 30, 2023 | 262,700,000 | |||||||||||||||||
End of period at Jun. 30, 2023 | $ 10,826 | $ 3 | 6,880 | 3,817 | (3) | $ (3) | 129 | $ 511 | 2,725 | $ 80 | 3,241 | $ 0 | $ 2,929 | $ 49 | 3,517 | |||
Shareholders' equity, end of year at Jun. 30, 2023 | $ 10,697 | 6,557 | 6,495 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share | $ 1.26 | |||||||||||||||||
Beginning of period at Mar. 31, 2023 | 6,861 | 3,745 | (2) | 129 | 2,725 | 3,139 | 3,388 | |||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 11 | |||||||||||||||||
Stock-based compensation activity | 8 | |||||||||||||||||
Net income | $ 239 | 103 | 103 | 130 | 130 | |||||||||||||
Net income attributable to Ameren common shareholders | 237 | 237 | ||||||||||||||||
Dividends on common stock | (165) | 0 | ||||||||||||||||
Preferred stock dividends | (1) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | (1) | (1) | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (2) | 2 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (2) | |||||||||||||||||
Common stock shares outstanding at beginning of period at Mar. 31, 2023 | 262,600,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 100,000 | |||||||||||||||||
Shares issued for stock-based compensation | 0 | |||||||||||||||||
Common stock shares outstanding at end of period at Jun. 30, 2023 | 262,700,000 | |||||||||||||||||
End of period at Jun. 30, 2023 | $ 10,826 | 3 | 6,880 | 3,817 | (3) | (3) | 129 | 511 | 2,725 | 80 | 3,241 | 0 | 2,929 | 49 | 3,517 | |||
Shareholders' equity, end of year at Jun. 30, 2023 | 10,697 | $ 6,557 | $ 6,495 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share | $ 0.63 | |||||||||||||||||
Beginning of period at Dec. 31, 2023 | $ 11,478 | 7,216 | 4,136 | (6) | 129 | 2,725 | 3,647 | 3,756 | ||||||||||
Common stock shares outstanding at beginning of period at Dec. 31, 2023 | 266,300,000 | 102,100,000 | 25,500,000 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued for stock-based compensation | 200,000 | |||||||||||||||||
Common stock shares outstanding at end of period at Mar. 31, 2024 | 266,600,000 | |||||||||||||||||
End of period at Mar. 31, 2024 | 7,228 | 4,219 | (7) | 129 | 2,725 | 3,672 | 3,971 | |||||||||||
Beginning of period at Dec. 31, 2023 | $ 11,478 | 7,216 | 4,136 | (6) | 129 | 2,725 | 3,647 | 3,756 | ||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 21 | |||||||||||||||||
Stock-based compensation activity | 9 | |||||||||||||||||
Net income | 522 | $ 155 | 155 | $ 340 | 340 | |||||||||||||
Net income attributable to Ameren common shareholders | 519 | 519 | ||||||||||||||||
Dividends on common stock | (356) | (25) | ||||||||||||||||
Preferred stock dividends | (2) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | (3) | (3) | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (3) | 3 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (3) | |||||||||||||||||
Common stock shares outstanding at beginning of period at Dec. 31, 2023 | 266,300,000 | 102,100,000 | 25,500,000 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 300,000 | |||||||||||||||||
Shares issued for stock-based compensation | 200,000 | |||||||||||||||||
Common stock shares outstanding at end of period at Jun. 30, 2024 | 266,800,000 | 102,100,000 | 25,500,000 | |||||||||||||||
End of period at Jun. 30, 2024 | $ 11,668 | 3 | 7,246 | 4,299 | (9) | (9) | 129 | 511 | 3,075 | 80 | 3,800 | 0 | 3,020 | 49 | 4,070 | |||
Shareholders' equity, end of year at Jun. 30, 2024 | $ 11,539 | 11,539 | $ 7,466 | $ 7,139 | ||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share | $ 1.34 | |||||||||||||||||
Beginning of period at Mar. 31, 2024 | 7,228 | 4,219 | (7) | 129 | 2,725 | 3,672 | 3,971 | |||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 11 | |||||||||||||||||
Stock-based compensation activity | 7 | |||||||||||||||||
Net income | $ 260 | $ 129 | 129 | $ 125 | 125 | |||||||||||||
Net income attributable to Ameren common shareholders | 258 | 258 | ||||||||||||||||
Dividends on common stock | (178) | (25) | ||||||||||||||||
Preferred stock dividends | (1) | (1) | ||||||||||||||||
Change in deferred retirement benefit costs | (2) | (2) | ||||||||||||||||
Net income attributable to noncontrolling interest holders | $ (2) | 2 | ||||||||||||||||
Dividends paid to noncontrolling interest holders | (2) | |||||||||||||||||
Common stock shares outstanding at beginning of period at Mar. 31, 2024 | 266,600,000 | |||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Shares issued under the DRPlus and 401(k) plan | 200,000 | |||||||||||||||||
Shares issued for stock-based compensation | 0 | |||||||||||||||||
Common stock shares outstanding at end of period at Jun. 30, 2024 | 266,800,000 | 102,100,000 | 25,500,000 | |||||||||||||||
End of period at Jun. 30, 2024 | $ 11,668 | $ 3 | $ 7,246 | $ 4,299 | $ (9) | $ (9) | $ 129 | $ 511 | $ 3,075 | $ 80 | $ 3,800 | $ 0 | $ 3,020 | $ 49 | $ 4,070 | |||
Shareholders' equity, end of year at Jun. 30, 2024 | $ 11,539 | $ 11,539 | $ 7,466 | $ 7,139 | ||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||
Dividends per common share | $ 0.67 |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 6 Months Ended |
Jun. 30, 2024 | |
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 also 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. 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 statement of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the 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 June 30, 2024, and December 31, 2023, Ameren had unconsolidated variable interests in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $75 million and $73 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 June 30, 2024, Ameren’s maximum exposure to loss related to these variable interests is limited to its investment of $75 million plus associated outstanding funding commitments of $12 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 June 30, 2024, the cash surrender value of COLI at Ameren and Ameren Illinois was $255 million (December 31, 2023 – $248 million) and $114 million (December 31, 2023 – $111 million), respectively, while total borrowings against the policies were $103 million (December 31, 2023 – $104 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 | 6 Months Ended |
Jun. 30, 2024 | |
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 2024 Electric Service Regulatory Rate Review In June 2024, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $446 million. The electric rate increase request is based on a 10.25% return on common equity, a capital structure composed of 52% common equity, a rate base of $14 billion, and a test year ended March 31, 2024, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2024. Ameren Missouri also requested the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and the utilization of production and investment tax credits or proceeds from the sale of tax credits allowed under the IRA, which the MoPSC previously authorized in earlier electric rate orders. 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. Included in these investments are 500 megawatts of solar generation investment for the Boomtown, Cass County and Huck Finn solar projects along with investments in the Callaway nuclear energy center and other dispatchable generation to support a reliable, low-cost and cleaner mix of energy resources; • decreased costs resulting from the planned retirement of the Rush Island Energy Center; and • decreased costs related to the extension of the retirement date of the Sioux Energy Center from 2030 to 2032, consistent with Ameren Missouri’s integrated resource plan filed with the MoPSC in September 2023, to ensure reliability. 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 May 2025 and new rates effective by June 2025. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be continued, 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. Generation Facilities During 2022 and 2023, Ameren Missouri, and certain subsidiaries of Ameren Missouri, entered into agreements to acquire and/or construct various generation facilities. The solar generation facilities are eligible for recovery under the PISA. The following table provides information with respect to each agreement: Agreement type Facility size Status of MoPSC CCN Status of FERC approval of acquisition Anticipated in-service date (a) Huck Finn Solar Project (b)(c) Build-transfer 200-MW Approved February 2023 Received March 2023 Fourth quarter 2024 Boomtown Solar Project (c)(d) Build-transfer 150-MW Approved April 2023 Received October 2023 Fourth quarter 2024 (e) Cass County Solar Project (d) Development-transfer (f) 150-MW Approved June 2024 Not applicable Fourth quarter 2024 Vandalia Solar Project (c)(g) Self-build 50-MW Approved March 2024 Not applicable Fourth quarter 2025 Bowling Green Solar Project (c)(g) Self-build 50-MW Approved March 2024 Not applicable First quarter 2026 Split Rail Solar Project (g) Build-transfer 300-MW Approved March 2024 Requested July 2024 Mid-2026 Castle Bluff Natural Gas Project Self-build 800-MW Filed June 2024 Not applicable Fourth quarter 2027 (a) Anticipated in-service dates are dependent on the timing of regulatory approvals and construction completion, among other things. (b) The Huck Finn Solar Project is expected to support Ameren Missouri’s compliance with the state of Missouri’s renewable energy standard. Investments in the project will be eligible for recovery under the RESRAM. Ameren Missouri expects to close on the acquisition of the Huck Finn Solar Project in the fourth quarter of 2024. (c) These projects collectively represent approximately $0.85 billion of expected capital expenditures. (d) The Boomtown and Cass County solar projects are expected to support Ameren Missouri’s transition to renewable energy generation and serve customers under the Renewable Solutions Program. (e) Ameren Missouri expects to close on the acquisition of the Boomtown Solar Project in August 2024. (f) In June 2024, Ameren Missouri acquired the Cass County Solar Project, which includes solar panels, project design, land rights, and engineering, procurement, and construction agreements, for approximately $250 million and took over construction management of the project. (g) These solar projects are expected to support Ameren Missouri’s transition to renewable energy generation. Securitization of Rush Island Energy Center Costs In June 2024, the MoPSC issued a financing order authorizing the issuance of securitized utility tariff bonds by a wholly owned, special purpose subsidiary of Ameren Missouri to finance approximately $470 million of costs related to the planned accelerated retirement of the Rush Island Energy Center, which includes the expected remaining unrecovered net plant balance associated with the facility, among other costs. Ameren Missouri initially petitioned the MoPSC in November 2023 to finance $519 million of costs. The difference between the initial petition and final financing order will be considered for recovery in future rate proceedings involving the securitized utility tariff charge or base rates. Ameren Missouri will collect the amounts necessary to repay the bonds over approximately 15 years from the date of bond issuance. The financing order also includes a determination that the decision to retire the Rush Island Energy Center was reasonable and prudent. The MoPSC did not make a determination regarding the prudency of Ameren Missouri's prior actions that resulted in the adverse ruling in the NSR and Clean Air Act litigation discussed in Note 9 – Commitments and Contingencies. However, claims regarding such actions could be considered in future regulatory proceedings. If future regulatory proceedings result in revenue reductions based on Ameren Missouri’s prior actions that resulted in the adverse ruling in the NSR and Clean Air Act litigation, it could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. In July 2024, the MoOPC filed a request for rehearing of the financing order. Ameren Missouri expects a decision on the rehearing request in August 2024. The decision on the rehearing request is subject to appeal. The timing of the issuance of securitized utility tariff bonds is dependent on the conclusion of any appeal process. MEEIA In January 2024, Ameren Missouri filed a proposed customer energy-efficiency plan with the MoPSC under the MEEIA. This filing proposed a three-year plan, which includes a portfolio of customer energy-efficiency programs, along with the continued use of the MEEIA rider, which allows Ameren Missouri to collect from customers its actual MEEIA program costs and related lost electric revenues. If the plan is approved, Ameren Missouri intends to invest $123 million annually in the proposed customer energy-efficiency programs from 2025 to 2027. In addition, Ameren Missouri requested performance incentives applicable to each plan year to earn revenues by achieving certain customer energy-efficiency savings and target spending goals. If 100% of the goals are achieved, Ameren Missouri would earn performance incentive revenues totaling $56 million over the three-year plan. Ameren Missouri also requested additional performance incentives applicable to each plan year totaling up to $14 million over the three-year plan, if Ameren Missouri exceeds 100% of the goals. In March 2024, the MoPSC staff and the MoOPC filed responses in opposition to the proposed customer energy-efficiency plan under the MEEIA. Ameren Missouri expects a decision by the MoPSC by October 2024, but cannot predict the ultimate outcome of this regulatory proceeding. MISO Long-Range Transmission Projects CCN In July 2022, the MISO approved the first tranche of projects related to a preliminary long-range transmission planning roadmap of projects through 2039. A portion of these projects were assigned or awarded via a competitive bid process to various utilities, including Ameren. In July 2024, ATXI filed a request for a CCN, among other things, with the MoPSC related to a portion of the MISO long-range transmission projects that it will construct within the MoPSC’s jurisdiction. A decision by the MoPSC is expected by mid-2025. Illinois MYRP In December 2023, the ICC issued an order in Ameren Illinois' MYRP proceeding approving base rates for electric distribution services for 2024 through 2027 and rejecting Ameren Illinois' Grid Plan, which was addressed as part of the MYRP proceeding. Rate changes consistent with the December 2023 order became effective in January 2024 and remained effective through late June 2024, when new rates became effective pursuant to the June 2024 ICC rehearing order discussed below. The December 2023 order adopted an alternative methodology to establish a rate base and revenue requirements for the years 2024 through 2027 using Ameren Illinois’ previously approved 2022 year-end rate base. In January 2024, the ICC partially denied a rehearing requested by Ameren Illinois to revise the allowed ROE in the December 2023 order and granted Ameren Illinois’ rehearing request to reconsider the rate base for each year of the MYRP and to include a base level of investments to maintain grid reliability in each year of the MYRP. In June 2024, the ICC issued an order on Ameren Illinois’ rehearing request, which revised the rate bases for Ameren Illinois’ MYRP test years to include investments for 2023 through 2027, among other things. New rates became effective in late June 2024. For additional information on the ICC’s June 2024 rehearing order, see the table below. In July 2024, Ameren Illinois filed a request for rehearing of the ICC’s June 2024 rehearing order to include an asset associated with other postretirement benefits in the rate base. Subsequently, in August 2024, the ICC denied the rehearing request. The ICC rehearing denial is subject to appeal. Also, in January 2024, Ameren Illinois filed an appeal of the December 2023 ICC order, including the 8.72% ROE, to the Illinois Appellate Court for the Fifth Judicial District. The court is under no deadline to address the appeal. In July 2024, Ameren Illinois filed an update to its revised Grid Plan and revised MYRP to update the requested revenue requirements for 2024 through 2027. In July 2024, the ICC staff filed its recommendation regarding Ameren Illinois’ revised MYRP. An ICC decision on the revised Grid Plan and updated revenue requirements is expected by the end of 2024 with rates effective in January 2025. The following table presents the approved revenue requirements and average annual rate base in the ICC’s June 2024 rehearing order, as well as the proposed revenue requirements and average annual rate base in Ameren Illinois’ July 2024 revised MYRP and the ICC staff’s July 2024 revised MYRP recommendation: Year Revenue Requirement (in millions) Average Annual Rate Base (in billions) ICC’s June 2024 Rehearing Order (a) : 2024 $1,196 $4.0 2025 $1,282 $4.3 2026 $1,350 $4.5 2027 $1,397 $4.7 Ameren Illinois’ July 2024 Revised MYRP (a) : 2024 $1,215 $4.3 2025 $1,300 $4.5 2026 $1,386 $4.8 2027 $1,446 $5.0 ICC Staff’s July 2024 Revised MYRP (a) : 2024 $1,201 $4.2 2025 $1,281 $4.4 2026 $1,361 $4.6 2027 $1,414 $4.8 (a) Based on an allowed ROE of 8.72% and a capital structure composed of 50% common equity. The ROE is under appeal, as discussed above. Using the 2023 revenue requirement as a starting point, the approved revenue requirements in the ICC’s June 2024 rehearing order represent a cumulative four-year increase of $285 million compared to a cumulative increase of $334 million in Ameren Illinois’ July 2024 revised MYRP and a cumulative increase of $302 million in the ICC staff’s July 2024 revised MYRP recommendation. Ameren Illinois cannot predict the ultimate outcome of the appeal to the Illinois Appellate Court for the Fifth Judicial District, its revised Grid Plan filing, or its request to update the associated MYRP revenue requirements for 2024 through 2027. 2023 Electric Distribution Revenue Requirement Reconciliation Adjustment Request In April 2024, Ameren Illinois filed for a reconciliation adjustment to its 2023 electric distribution service revenue requirement with the ICC. In July 2024, Ameren Illinois filed a revised reconciliation adjustment, requesting recovery of $158 million. The reconciliation adjustment reflects a capital structure composed of 50% common equity and Ameren Illinois’ actual 2023 recoverable costs and year-end rate base. In June 2024, the ICC staff submitted its calculation of the reconciliation adjustment, recommending recovery of $157 million. An ICC decision in this proceeding is required by December 2024, and any approved adjustment would be collected from customers in 2025. This is the final revenue requirement reconciliation under the IEIMA formula framework. Electric Customer Energy-Efficiency Investments In May 2024, Ameren Illinois filed its annual electric energy-efficiency formula rate update to increase its rates by $26 million with the ICC. An ICC decision in this proceeding is required by December 2024, with new rates effective January 2025. 2023 Natural Gas Delivery Service Rate Order In November 2023, the ICC issued an order in Ameren Illinois’ January 2023 natural gas delivery service regulatory rate review, which resulted in an increase to its annual revenues for natural gas delivery service of $112 million based on a 9.44% allowed ROE, a capital structure composed of 50% common equity, and a rate base of approximately $2.85 billion. The order reflected a reduction of approximately $93 million of planned distribution and transmission capital investments included in Ameren Illinois’ requested revenue increase, which used a 2024 future test year. The new rates became effective on November 28, 2023. In December 2023, Ameren Illinois filed a request for rehearing of the ICC’s November 2023 order. The filing requested the ICC revise the order to include an allowed ROE of at least 9.89%, a capital structure composed of 52% common equity, and the reversal of the approximately $93 million reduction of planned distribution and transmission capital investments included in the order, among other things. In January 2024, the ICC denied Ameren Illinois’ rehearing request. Subsequently, in January 2024, Ameren Illinois filed an appeal of the November 2023 ICC order to the Illinois Appellate Court for the Fifth Judicial District. The court is under no deadline to address the appeal. Ameren Illinois cannot predict the ultimate outcome of this appeal. QIP Reconciliation Hearing In March 2021, Ameren Illinois filed a request with the ICC to initiate a reconciliation proceeding to determine the accuracy and prudence of natural gas capital investments recovered under the QIP rider during 2020. In October 2023, the Illinois Attorney General’s office challenged the recovery of capital investments that were made during 2020, alleging that the ICC should disallow approximately $53 million in natural gas capital investments as improper and imprudent, providing a potential over-recovery of approximately $3 million in 2020. In October 2023, the ICC staff filed testimony that supports the prudence and reasonableness of the capital investments made during 2020. Ameren Illinois’ 2020 QIP rate recovery request under review by the ICC was within the rate increase limitations allowed by law. The ICC is under no deadline to issue an order in this proceeding. Ameren Illinois cannot predict the ultimate outcome of this regulatory proceeding. MISO Long-Range Transmission Projects CCN In July 2022, the MISO approved the first tranche of projects related to a preliminary long-range transmission planning roadmap of projects through 2039. A portion of these projects were assigned or awarded via a competitive bidding process to various utilities, including Ameren. In February 2024, Ameren Illinois and ATXI filed a request for a CCN, among other things, with the ICC related to the portion of the MISO long-range transmission projects they will construct within the ICC’s jurisdiction. A decision by the ICC is expected by mid-2025. Federal 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 court elected not to rule on the issues raised by Ameren Missouri, Ameren Illinois, and ATXI. The currently allowed base ROE of 10.02% will remain effective for customer billings, but the transmission rates charged during previous periods and the currently effective rates may be 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 $21 million and $15 million, respectively, based on each company’s 2024 projected rate base. Ameren and Ameren Illinois are unable to predict the ultimate resolution of this matter; however, such resolution could have a material effect on their results of operations, financial position, and liquidity. |
Short-Term Debt And Liquidity
Short-Term Debt And Liquidity | 6 Months Ended |
Jun. 30, 2024 | |
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, of the Form 10-K for a description of our indebtedness provisions and other covenants as well as a description of money pool agreements. 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 June 30, 2024, 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 $1.9 billion. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of June 30, 2024. As of June 30, 2024, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were 61%, 49%, and 45% for Ameren, Ameren Missouri, and Ameren Illinois, respectively. The following table presents commercial paper outstanding, net of issuance discounts, as of June 30, 2024, and December 31, 2023. There were no borrowings outstanding under the Credit Agreements as of June 30, 2024, or December 31, 2023. June 30, 2024 December 31, 2023 Ameren (parent) $ 301 $ — Ameren Missouri 390 170 Ameren Illinois — 366 Ameren consolidated $ 691 $ 536 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 six months ended June 30, 2024 and 2023: Ameren Ameren Ameren Ameren 2024 Average daily amount outstanding $ 84 $ 109 $ 385 $ 578 Weighted-average interest rate 5.55 % 5.53 % 5.57 % 5.56 % Peak amount outstanding during period (a) $ 301 $ 509 $ 694 $ 1,084 Peak interest rate 5.60 % 5.68 % 5.68 % 5.68 % 2023 Average daily amount outstanding $ 595 $ 343 $ 230 $ 1,168 Weighted-average interest rate 5.14 % 5.04 % 5.10 % 5.10 % Peak amount outstanding during period (a) $ 841 $ 592 $ 450 $ 1,381 Peak interest rate 5.55 % 5.55 % 5.60 % 5.60 % (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 amount 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 six months ended June 30, 2024, was 5.51% and 5.41%, respectively (2023 – 5.28% and 5.04%, respectively). See Note 8 – Related-party Transactions for the amount of interest income and expense from the utility money pool agreements recorded by Ameren Missouri and Ameren Illinois for the three and six months ended June 30, 2024 and 2023. |
Long-Term Debt And Equity Finan
Long-Term Debt And Equity Financings | 6 Months Ended |
Jun. 30, 2024 | |
Long-Term Debt And Equity Financings [Abstract] | |
LONG-TERM DEBT AND EQUITY FINANCINGS | LONG-TERM DEBT AND EQUITY FINANCINGS Ameren For the three and six months ended June 30, 2024, Ameren issued a total of 0.2 million and 0.3 million shares of common stock, under its DRPlus and 401(k) plan, and received proceeds of $4 million and $14 million, respectively. As of June 30, 2024, Ameren had a receivable of $7 million related to issuances of common stock under its DRPlus. In addition, in the first quarter of 2024, Ameren issued 0.2 million shares of common stock valued at $16 million upon the settlement of stock-based compensation awards. There were no shares issued under the ATM program for the three and six months ended June 30, 2024. As of June 30, 2024, Ameren had approximately $770 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of June 30, 2024, discussed below. The forward sale agreements outstanding as of June 30, 2024, can be settled at Ameren’s discretion on or prior to dates ranging from October 3, 2024 to February 28, 2025. 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 $76.69 to $89.31, with an average initial forward sale price of $80.45. 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 June 30, 2024, Ameren could have settled the forward sale agreements with physical delivery of 2.9 million shares of common stock to the respective counterparties in exchange for cash of $232 million. Alternatively, the forward sale agreements could have also been settled at June 30, 2024, with the counterparties delivering approximately $29 million of cash or approximately 0.4 million shares of common stock to Ameren. In connection with the forward sale agreements outstanding at June 30, 2024, the various counterparties, or their affiliates, borrowed from third parties and sold 2.9 million shares of common stock. The gross sales price of these shares totaled $232 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 January 2024, Ameren Missouri issued $350 million of 5.25% first mortgage bonds due January 2054, with interest payable semiannually on January 15 and July 15 of each year, beginning July 15, 2024. Net proceeds from this issuance were used for capital expenditures and to repay short-term debt. In April 2024, Ameren Missouri issued $500 million of 5.20% first mortgage bonds due April 2034, with interest payable semiannually on April 1 and October 1 of each year, beginning October 1, 2024. Net proceeds from this issuance were used for capital expenditures and to repay short-term debt. In April 2024, $350 million principal amount of Ameren Missouri’s 3.50% senior secured notes matured and were repaid with cash on hand. Ameren Missouri received capital contributions totaling $350 million from Ameren (parent) during the three and six months ended June 30, 2024. Ameren Illinois In June 2024, Ameren Illinois issued $625 million of 5.55% first mortgage bonds due July 2054, with interest payable semiannually on January 1 and July 1 of each year, beginning January 1, 2025. Net proceeds from this issuance were used to repay short-term debt. Indenture Provisions and Other Covenants See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for a description of our indenture provisions and other covenants, as well as restrictions on the payment of dividends. At June 30, 2024, 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 June 30, 2024, none of the Ameren Companies had any material off-balance-sheet financing arrangements, other than their investment in 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 | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren: Allowance for equity funds used during construction $ 16 $ 14 $ 25 $ 23 Other interest income 13 9 21 17 Non-service cost components of net periodic benefit income (a) 76 63 152 127 Miscellaneous income 4 2 6 4 Earnings related to equity method investments 1 — 1 2 Donations (2) (2) (4) (4) Miscellaneous expense (5) (4) (9) (9) Total Other Income, Net $ 103 $ 82 $ 192 $ 160 Ameren Missouri: Allowance for equity funds used during construction $ 14 $ 8 $ 23 $ 12 Other interest income 3 2 5 6 Non-service cost components of net periodic benefit income (a) 35 14 69 28 Miscellaneous income — 1 2 2 Donations (1) (1) (2) (2) Miscellaneous expense (2) (2) (4) (5) Total Other Income, Net $ 49 $ 22 $ 93 $ 41 Ameren Illinois: Allowance for equity funds used during construction $ 2 $ 6 $ 2 $ 10 Other interest income 9 6 15 10 Non-service cost components of net periodic benefit income 26 31 53 62 Miscellaneous income 2 1 3 2 Donations (1) (1) (2) (2) Miscellaneous expense (1) (2) (3) (4) Total Other Income, Net $ 37 $ 41 $ 68 $ 78 (a) For the three and six months ended June 30, 2024, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $(11) million and $(20) 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 $17 million and $34 million, respectively, for the three and six months ended June 30, 2023. See Note 11 – Retirement Benefits for additional information. |
Derivative Financial Instrument
Derivative Financial Instruments | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024, and December 31, 2023, all contracts that met the definition of a derivative and were not eligible for the NPNS exception received regulatory deferral. The cash flows from our derivative financial instruments follow the cash flow classification of the hedged item. The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of June 30, 2024, and December 31, 2023. As of June 30, 2024, these contracts extended through October 2027, October 2029 and May 2032 for fuel oils, natural gas and power, respectively. Quantity (in millions) June 30, 2024 December 31, 2023 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) 20 — 20 17 — 17 Natural gas (in mmbtu) 52 221 273 53 218 271 Power (in MWhs) — 5 5 — 5 5 Uranium (pounds in thousands) — — — 186 — 186 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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Balance Sheet Location Ameren Ameren Ameren Ameren Ameren Ameren Fuel oils Other current assets $ 2 $ — $ 2 $ 2 $ — $ 2 Natural gas Other current assets 1 3 4 — — — Other assets 2 1 3 3 3 6 Power Other current assets 15 — 15 5 — 5 Uranium Other current assets — — — 9 — 9 Total assets $ 20 $ 4 $ 24 $ 19 $ 3 $ 22 Fuel oils Other current liabilities $ 1 $ — $ 1 $ 1 $ — $ 1 Other deferred credits and liabilities — — — 1 — 1 Natural gas Other current liabilities 9 33 42 12 45 57 Other deferred credits and liabilities 8 28 36 10 30 40 Power Other current liabilities 1 11 12 1 12 13 Other deferred credits and liabilities — 50 50 — 56 56 Total liabilities $ 19 $ 122 $ 141 $ 25 $ 143 $ 168 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. Th e following table p rovides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of June 30, 2024, and December 31, 2023: Gross Amounts Not Offset in the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount June 30, 2024 Assets: Ameren Missouri $ 20 $ 5 $ — $ 15 Ameren Illinois 4 2 — 2 Ameren $ 24 $ 7 $ — $ 17 Liabilities: Ameren Missouri $ 19 $ 5 $ — $ 14 Ameren Illinois 122 2 — 120 Ameren $ 141 $ 7 $ — $ 134 December 31, 2023 Assets: Ameren Missouri $ 19 $ 6 $ — $ 13 Ameren Illinois 3 1 — 2 Ameren $ 22 $ 7 $ — $ 15 Liabilities: Ameren Missouri $ 25 $ 6 $ — $ 19 Ameren Illinois 143 1 6 136 Ameren $ 168 $ 7 $ 6 $ 155 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. 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 June 30, 2024, if counterparty groups were to fail completely to perform on contracts, the Ameren Companies’ maximum exposure related to derivative assets, predominantly from financial institutions, would have been immaterial with or without consideration of the application of master netting arrangements or similar agreements and collateral held. 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. The following table presents, as of June 30, 2024, the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require: Aggregate Fair Value of Derivative Liabilities (a) Cash Potential Aggregate Amount of Additional Collateral Required (b) Ameren Missouri $ 19 $ — $ 13 Ameren Illinois 61 — 59 Ameren $ 80 $ — $ 72 (a) Before consideration of master netting arrangements or similar agreements. (b) |
Fair Value Measurements
Fair Value Measurements | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 or 2023. At June 30, 2024, and December 31, 2023, 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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Ameren Missouri Derivative assets – commodity contracts: Fuel oils $ 1 $ — $ 1 $ 2 $ 2 $ — $ — $ 2 Natural gas — 3 — 3 — 3 — 3 Power — — 15 15 — — 5 5 Uranium — — — — — — 9 9 Total derivative assets – commodity contracts $ 1 $ 3 $ 16 $ 20 $ 2 $ 3 $ 14 $ 19 Nuclear decommissioning trust fund: Equity securities: U.S. large capitalization $ 842 $ — $ — $ 842 $ 787 $ — $ — $ 787 Debt securities: U.S. Treasury and agency securities — 178 — 178 — 150 — 150 Corporate bonds — 154 — 154 — 136 — 136 Other — 82 — 82 — 68 — 68 Total nuclear decommissioning trust fund $ 842 $ 414 $ — $ 1,256 (a) $ 787 $ 354 $ — $ 1,141 (a) Total Ameren Missouri $ 843 $ 417 $ 16 $ 1,276 $ 789 $ 357 $ 14 $ 1,160 Ameren Illinois Derivative assets – commodity contracts: Natural gas — 1 3 4 — 1 2 3 Total Ameren Illinois $ — $ 1 $ 3 $ 4 $ — $ 1 $ 2 $ 3 Ameren Derivative assets – commodity contracts (b) $ 1 $ 4 $ 19 $ 24 $ 2 $ 4 $ 16 $ 22 Nuclear decommissioning trust fund (c) 842 414 — 1,256 (a) 787 354 — 1,141 (a) Total Ameren $ 843 $ 418 $ 19 $ 1,280 $ 789 $ 358 $ 16 $ 1,163 Liabilities: Ameren Missouri Derivative liabilities – commodity contracts: Fuel oils $ 1 $ — $ — $ 1 $ 2 $ — $ — $ 2 Natural gas — 16 1 17 — 19 3 22 Power — — 1 1 — — 1 1 Total Ameren Missouri $ 1 $ 16 $ 2 $ 19 $ 2 $ 19 $ 4 $ 25 Ameren Illinois Derivative liabilities – commodity contracts: Natural gas $ 2 $ 52 $ 7 $ 61 $ 4 $ 60 $ 11 $ 75 Power — — 61 61 — — 68 68 Total Ameren Illinois $ 2 $ 52 $ 68 $ 122 $ 4 $ 60 $ 79 $ 143 Ameren Derivative liabilities – commodity contracts (b) $ 3 $ 68 $ 70 $ 141 $ 6 $ 79 $ 83 $ 168 (a) Balance excludes $10 million and $9 million of cash and cash equivalents, receivables, payables, and accrued income, net, for June 30, 2024, and December 31, 2023, 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 six months ended June 30, 2024 and 2023: 2024 2023 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren For the three months ended June 30: Beginning balance at April 1 $ 2 $ (54) $ (52) $ 5 $ (52) $ (47) Realized and unrealized gains/(losses) included in regulatory assets/liabilities 15 (12) 3 14 (20) (6) Settlements (3) 5 2 (5) 4 (1) Ending balance at June 30 $ 14 $ (61) $ (47) $ 14 $ (68) $ (54) Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ 14 $ (12) $ 2 $ 14 $ (20) $ (6) For the six months ended June 30: Beginning balance at January 1 $ 4 $ (68) $ (64) $ 12 $ (33) $ (21) Realized and unrealized gains/(losses) included in regulatory assets/liabilities 14 (2) 12 8 (41) (33) Settlements (4) 9 5 (6) 6 — Ending balance at June 30 $ 14 $ (61) $ (47) $ 14 $ (68) $ (54) Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ 14 $ — $ 14 $ 14 $ (35) $ (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 June 30, 2024, and December 31, 2023: Fair Value Weighted Average (b) Commodity Assets Liabilities Valuation Technique(s) Unobservable Input (a) Range 2024 Power (c) $ 15 $ (62) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 33 – 70 43 Nodal basis ($/MWh) (10) – (1) (5) 2023 Power (c) $ 5 $ (69) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 31 – 65 43 Nodal basis ($/MWh) (8) – (1) (5) (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 use visible forward prices adjusted for nodal-to-hub basis differentials. The following table sets forth the carrying amount and, by level within the fair value hierarchy, the fair value of long-term debt (including current portion) disclosed, but not recorded, at fair value as of June 30, 2024, and December 31, 2023: Long-Term Debt (Including Current Portion): Carrying Amount (a) Fair Value Level 2 Level 3 Total June 30, 2024 Ameren $ 17,079 $ 14,990 $ 460 (b) $ 15,450 Ameren Missouri 6,830 6,069 — 6,069 Ameren Illinois 5,851 5,251 — 5,251 December 31, 2023 Ameren $ 15,970 $ 14,366 $ 467 (b) $ 14,833 Ameren Missouri 6,341 5,800 — 5,800 Ameren Illinois 5,232 4,867 — 4,867 (a) Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $124 million, $53 million, and $52 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of June 30, 2024. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $111 million, $45 million, and $47 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2023. (b) The Level 3 fair value amount consists of ATXI’s senior unsecured notes. The Ameren Companies’ carrying amounts of cash, cash equivalents, and restricted cash approximate fair value and are considered Level 1 in the fair value hierarchy. The Ameren Companies’ short-term borrowings approximate fair value because of the short-term nature of these instruments and are considered Level 2 in the fair value hierarchy. |
Related Party Transactions
Related Party Transactions | 6 Months Ended |
Jun. 30, 2024 | |
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 agreements, 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 $22 million and $24 million, respectively, as of June 30, 2024, and $31 million and $34 million, respectively, as of December 31, 2023, related to Ameren Services’ allocated portion of Ameren’s pension and postretirement benefit plans. In December 2023, ATXI placed in service a transmission operations control center. Rental revenues received by ATXI from Ameren Services associated with this facility are affiliate transactions and are eliminated in consolidation for Ameren’s consolidated financial statements. Ameren Services’ rental expenses incurred are subsequently allocated to Ameren Missouri and Ameren Illinois as part of the Ameren Services support agreement. 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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Income taxes payable to parent (a) $ — $ 44 $ — $ 2 Income taxes receivable from parent (b) 54 — 56 22 (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 six months ended June 30, 2024 and 2023: Three Months Six Months Agreement Income Statement Ameren Ameren Ameren Ameren Ameren Missouri power supply Operating Revenues 2024 $ (b) $ (a) $ (b) $ (a) agreements with Ameren Illinois 2023 (b) (a) (b) (a) Ameren Missouri and Ameren Illinois Operating Revenues 2024 $ 8 $ (b) $ 15 $ (b) rent and facility services 2023 8 (b) 18 (b) Ameren Missouri and Ameren Illinois miscellaneous Operating Revenues 2024 $ 1 $ (b) $ 1 $ 1 support services 2023 (b) (b) (b) (b) Total Operating Revenues 2024 $ 9 $ (b) $ 16 $ 1 2023 8 (b) 18 (b) Ameren Illinois power supply Purchased Power 2024 $ (a) $ (b) $ (a) $ (b) agreements with Ameren Missouri 2023 (a) (b) (a) (b) Ameren Missouri and Ameren Illinois Purchased Power 2024 $ 2 $ 1 $ 4 $ 1 transmission services from ATXI 2023 1 (b) 1 (b) Total Purchased Power 2024 $ 2 $ 1 $ 4 $ 1 2023 1 (b) 1 (b) Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2024 $ (b) $ (b) $ (b) $ (b) rent and facility services 2023 (b) (b) (b) 2 Ameren Services support services Other Operations and Maintenance 2024 $ 43 $ 40 $ 81 $ 77 agreement 2023 35 33 70 68 Total Other Operations and 2024 $ 43 $ 40 $ 81 $ 77 Maintenance 2023 35 33 70 70 Money pool interest (Interest Charges)/Other Income, Net 2024 $ (b) $ (b) $ (3) $ (2) 2023 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Commitments And Contingencies
Commitments And Contingencies | 6 Months Ended |
Jun. 30, 2024 | |
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 by 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 energy-related 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 requirements of environmental laws. 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, NO x , mercury, toxic metals and acid gases, and CO 2 emissions. Regulations implementing the Clean Water Act govern both intake and discharges of water, as well as evaluation of the ecological and biological impact of those 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 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. Since 2021, Ameren Missouri’s High Prairie Renewable Energy Center curtailed nighttime operations from April through October to limit impacts on protected species during the critical biological season. Seasonal nighttime curtailment began again in April 2024, but the extent and duration of the curtailment is currently unknown as assessment of mitigation technologies is ongoing. Ameren Missouri does not anticipate these operating curtailments will have a material impact on its results of operations, financial position, or liquidity. Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $90 million to $120 million from 2024 through 2028 to comply with environmental regulations. These estimates exclude capital expenditures that may be necessary to comply with regulations issued by the EPA in 2024 relating to CO 2 emissions, MATS, effluent limitations guidelines, and CCR management, which Ameren and Ameren Missouri are assessing and are discussed below. Additional capital expenditures for environmental controls beyond 2028 could be required. This estimate of capital expenditures includes surface impoundment closure and corrective action measures required by the 2015 CCR Rule and modifications to cooling water intake structures at existing power plants under Clean Water Act rules in place prior to 2024, all of which are discussed below. In addition to planned retirements of coal-fired energy centers identified in the 2023 IRP filed with the MoPSC in September 2023 and as noted below with respect to the NSR and Clean Air Act litigation and Illinois emissions standards discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of the Form 10-K, 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 by state regulators and the EPA, revisions to regulatory obligations, and varying cost of potential compliance strategies, among other things. The following sections describe the more significant environmental statutes and regulations and environmental enforcement and remediation matters that affect or could affect our operations. The EPA periodically amends and revises its regulations and proposes amendments to regulations and guidelines, which could ultimately result in the revision of all or part of such regulations. Clean Air Act Federal and state laws, including the 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. In April 2022, the EPA proposed the Good Neighbor Rule of the Clean Air Act, which includes additional NO x emission reductions from power plants in Missouri, Illinois, and other states through revisions to the CSAPR. In January 2023, the EPA issued its final disapproval of Missouri’s proposed state implementation plan for addressing the transport of ozone under the Good Neighbor Rule of the Clean Air Act. The disapproval of the state plan allows the EPA to implement revisions to the CSAPR through a federal implementation plan. In March 2023, the EPA announced federal implementation plan requirements, which were subsequently published to the Federal Register in June 2023, reducing the amount of NOx allowances available for state budgets and imposing NO x emission limits on electric generating units for Missouri, Illinois, and other states under the Good Neighbor Rule of the Clean Air Act. In April 2023, the Missouri Attorney General and Ameren Missouri separately filed lawsuits in the United States Court of Appeals for the Eighth Circuit challenging the EPA’s disapproval of the Missouri state plan and sought a stay of the EPA’s disapproval of the Missouri state plan. The United States Court of Appeals for the Eighth Circuit in May 2023 granted those stay motions thereby preventing the EPA from imposing the federal implementation plan until the court of appeals issues a ruling. In June 2024, the United States Supreme Court granted applications to stay the EPA’s imposition of the federal implementation plan until resolution of appellate court challenges. Ameren Missouri complies with the 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 existing NO x air pollution control equipment. Reducing the amount of state budget NO x allowances for compliance with NO x emission limits could result in additional controls being required on Ameren Missouri’s generating units and/or the reduction of operations. Any additional costs for compliance are expected to be recovered from customers, subject to MoPSC prudence review, 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, clarifying that there are limits on how the EPA may regulate greenhouse gases absent further direction from the United States Congress. The court concluded that the EPA’s proposed rules were designed to shift generation from fossil-fuel-fired power plants to renewable energy facilities, which was improper absent specific congressional authorization. In response to that ruling, in April 2024, the EPA issued a final rule that sets CO 2 emission standards for existing coal-fired and new natural gas-fired power plants that relies on the adoption of carbon capture technology and/or natural gas co-firing for coal-fired power plants and carbon capture technology for new natural gas-fired power plants. Affected power plants are required to comply with the rule through a phased-in approach or retire. In July 2024, the United States Court of Appeals for the District of Columbia Circuit denied a request for stay by various stakeholders including state attorney generals and industry groups but indicated it would establish an expedited schedule regarding the legal merits of the final rule. Subsequently in July 2024, motions for stay of the final rule were filed with the United States Supreme Court. Ameren and Ameren Missouri are monitoring the legal challenges and assessing the impacts of the final rule and, at this time, cannot predict the impacts on their results of operations, financial position, and liquidity. MATS In April 2024, the EPA revised the MATS by establishing a more stringent standard for emissions of particulate matter, requiring the use of continuous emissions monitoring systems. Ameren and Ameren Missouri are assessing the impacts of the revised rule and, at this time, cannot predict the impacts on their results of operations, financial position, and liquidity. 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 September 2023, the district court granted Ameren Missouri’s request to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected retirement date of 2039 in lieu of installing a flue gas desulfurization system. In its amended remedy order, the district court established an October 15, 2024 retirement date to allow for the completion of various transmission reliability projects and, in the interim, authorized Ameren Missouri to operate the energy center only as needed and as directed by the MISO. The United States Department of Justice is seeking an order from the district court providing for additional mitigation relief related to prior emissions. Ameren Missouri contends that the retirement of the Rush Island Energy Center, which eliminates all future emissions from the energy center, mitigates claims relating to prior emissions. In March 2024, the district court ordered Ameren Missouri and the United States Department of Justice to file proposed draft orders outlining additional mitigation relief. In May 2024, Ameren Missouri filed a proposed draft order that includes retiring the Rush Island Energy Center, a program to provide electric buses and charging stations to schools in the metro St. Louis area, a program to provide air filters to eligible Ameren Missouri electric residential customers, and the retirement of SO 2 allowances. Excluding the accelerated retirement of the Rush Island Energy Center, these programs are estimated to cost approximately $20 million. Also in May 2024, the United States Department of Justice filed a proposed draft order that includes a program to provide electric buses and charging stations to schools in the metro St. Louis area and a program to provide air filters to eligible Ameren Missouri electric residential customers. These programs include a significantly greater number of buses, charging stations, and air filters than Ameren Missouri’s proposal and the United States Department of Justice estimates these programs would cost approximately $120 million. A mediation proceeding related to the potential additional mitigation relief is scheduled for September 2024. As of June 30, 2024, Ameren and Ameren Missouri recorded a $20 million liability in “Other current liabilities” on their consolidated balance sheets related to the cost of potential additional mitigation, which represents the estimated minimum liability, as no other amount within the range was a better estimate. Ameren Missouri could be required to implement some or all of the additional mitigation relief programs included in the United States Department of Justice’s proposed draft order, the costs of which could be material and could adversely impact Ameren and Ameren Missouri’s results of operations and financial position. Depending on the scope and basis of any final order issued by the district court, which is expected by the end of 2024, Ameren Missouri or the United States Department of Justice could appeal any additional mitigation relief ordered. The MISO designated the Rush Island Energy Center as a system support resource in 2022 and concluded that certain reliability mitigation measures, including transmission upgrades, should occur before the energy center is retired. The Rush Island Energy Center began operating as a system support resource on September 1, 2022. In 2024, the MISO extended the system support resource designation through Rush Island Energy Center’s retirement date of October 15, 2024. In July 2024, an agreement between Ameren Missouri and the MISO was filed with the FERC for approval regarding the continued operation of the energy center during peak demand times and emergencies. Construction activities are ongoing for the transmission upgrades approved by the MISO, with the majority of the upgrades expected to be completed in the fall of 2024. Ameren Missouri expects to complete the last of the necessary upgrades by mid-2025. 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 Part II, Item 8, of the Form 10-K for additional information. In connection with the accelerated retirement of the Rush Island Energy Center, the MoPSC issued an order in June 2024 authorizing Ameren Missouri 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 Missouri’s securitization statute. Costs associated with the retirement would exclude any additional mitigation relief ordered in the NSR and Clean Air Act litigation discussed above. See Note 2 – Rate and Regulatory Matters for additional information. As of June 30, 2024, the Rush Island Energy Center had a net plant balance of $508 million included in plant to be abandoned, net, within “Property, Plant, and Equipment, Net”. 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. Clean Water Act Among other items, the Clean Water Act requires 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 this 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 comply with these guidelines, Ameren Missouri installed dry ash handling systems and wastewater treatment facilities at its coal-fired energy centers. In April 2024, the EPA issued new effluent limitation guidelines that established a zero discharge limit for flue gas desulfurization wastewater, bottom ash transport water, and combustion residual leachate. Ameren and Ameren Missouri expect the impacts of the new guidelines on their results of operations, financial position, and liquidity to be immaterial. CCR Management The EPA’s 2015 CCR Rule establishes requirements for the management and disposal of CCR from coal-fired power plants and has resulted in the closure of surface impoundments at Ameren Missouri’s energy centers, with closures of surface impoundments in process at its Sioux Energy Center and retired Meramec Energy Center. Ameren Missouri plans to substantially complete the closures of remaining surface impoundments by the end of 2026. Ameren Missouri’s CCR management compliance plan includes installation of groundwater monitoring equipment and groundwater treatment facilities. In April 2024, the EPA revised the CCR Rule to impose groundwater monitoring, and corrective action, closure, and post-closure requirements on certain active and inactive CCR surface impoundments and management disposal units. Ameren and Ameren Missouri have AROs of $42 million associated with CCR storage facilities recorded on their respective balance sheets as of June 30, 2024. This amount includes an immaterial incremental ARO related to the 2024 CCR Rule, which will be revised as additional site studies are performed. Ameren and Ameren Missouri are assessing the impacts of this rule revision and, at this time, cannot predict the final impacts on their results of operations, financial position, and liquidity. 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 June 30, 2024, Ameren Illinois has remediated the majority of the 44 former MGP sites in Illinois with an estimated remaining obligation primarily related to three of these former MGP sites at $45 million to $95 million. Ameren and Ameren Illinois recorded a liability of $45 million to represent the estimated minimum obligation for these sites, as no other amount within the range was a better estimate. Ameren cannot estimate the completion date of the estimated remaining obligation due to site accessibility, among other things. 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 impacted, regulatory changes, local ordinances, and site accessibility. The actual costs and timing of completion may vary substantially from these estimates. The ICC allows Ameren Illinois to recover MGP 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. 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, including additional or more stringent cleanup standards, or will affect our results of operations, financial position, or liquidity. |
Callaway Energy Center
Callaway Energy Center | 6 Months Ended |
Jun. 30, 2024 | |
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 December 2023 and is reflected within the ARO. Ameren Missouri’s filing supported no change in electric service rates for decommissioning costs. There is no deadline by which the MoPSC must issue an order regarding the filing. See Note 13 – Supplemental Information for more information on Ameren Missouri’s AROs. Insurance The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at April 1, 2024: Type and Source of Coverage Most Recent Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers January 1, 2024 $ 500 $ — Pool participation (a) 15,763 (a) 166 (b) $ 16,263 (c) $ 166 Property damage: NEIL and EMANI April 1, 2024 $ 3,200 (d) $ 28 (e) Accidental outage: NEIL April 1, 2024 $ 490 (f) $ 11 (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 $500 million in the event of an incident at any licensed United States commercial reactor, payable at $24.7 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 $0.7 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 $291 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 October 2023. 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 insurance limits, 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 | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2024 2023 2024 2023 2024 2023 2024 2023 Service cost (a) $ 23 $ 23 $ 44 $ 46 $ 3 $ 3 $ 6 $ 6 Non-service cost components: Interest cost 56 56 111 111 11 12 22 23 Expected return on plan assets (b) (82) (84) (164) (167) (23) (23) (46) (46) Amortization of (b) : Prior service benefit — — — — (1) (1) (2) (2) Actuarial (gain) (16) (28) (33) (57) (10) (12) (20) (23) Total non-service cost components (c) $ (42) $ (56) $ (86) $ (113) $ (23) $ (24) $ (46) $ (48) Net periodic benefit income (d) $ (19) $ (33) $ (42) $ (67) $ (20) $ (21) $ (40) $ (42) (a) Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income. (b) Prior service benefit is amortized on a straight-line basis over the average future service of active participants benefiting under a plan amendment. Net actuarial gains or losses related to the net benefit obligation subject to amortization are amortized on a straight-line basis over 10 years. The difference between the actual and expected return on plan assets is amortized over 4 years. (c) Non-service cost components are reflected in “Other Income, Net” on Ameren’s consolidated statement of income. See Note 5 – Other Income, Net for additional information. (d) Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) 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 six months ended June 30, 2024 and 2023: Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2024 2023 2024 2023 2024 2023 2024 2023 Ameren Missouri (a) $ (10) $ (17) $ (22) $ (35) $ (7) $ (7) $ (14) $ (15) Ameren Illinois (8) (13) (17) (27) (13) (14) (26) (27) Other (1) (3) (3) (5) — — — — Ameren (a) $ (19) $ (33) $ (42) $ (67) $ (20) $ (21) $ (40) $ (42) (a) Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) incurred by Ameren Missouri under GAAP and the level of such costs included in rates. |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Ameren Ameren Missouri Ameren Illinois 2024 2023 2024 2023 2024 2023 Three Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of excess deferred taxes (a) (8) (7) (14) (15) (4) (2) Renewable and other tax credits (b) (4) (5) (8) (10) — — State tax 5 5 3 3 7 7 Depreciation differences (1) — (1) — — (1) Effective income tax rate 13 % 14 % 1 % (1) % 24 % 25 % Six Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of excess deferred taxes (a) (8) (8) (14) (15) (4) (2) Renewable and other tax credits (b) (4) (4) (8) (10) — — State tax 5 5 3 3 7 7 Depreciation differences — — — — — (1) Other permanent items — (1) — — — — Effective income tax rate 14 % 13 % 2 % (1) % 24 % 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) |
Supplemental Information
Supplemental Information | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Ameren Ameren Ameren Ameren Ameren Ameren “Cash and cash equivalents” $ 19 $ — $ 6 $ 25 $ — $ — Restricted cash included in “Other current assets” 18 7 7 13 5 5 Restricted cash included in “Other assets” 260 — 260 229 — 229 Restricted cash included in “Nuclear decommissioning trust fund” 4 4 — 5 5 — Total cash, cash equivalents, and restricted cash $ 301 $ 11 $ 273 $ 272 $ 10 $ 234 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 June 30, 2024, and December 31, 2023, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of $49 million and $42 million, respectively. The following table provides a reconciliation of the beginning and ending amount of the allowance for doubtful accounts for the three and six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren: Beginning of period $ 37 $ 34 $ 30 $ 31 Bad debt expense 6 13 16 23 Charged to other accounts (a) 1 1 4 1 Net write-offs (7) (9) (13) (16) End of period $ 37 $ 39 $ 37 $ 39 Ameren Missouri: Beginning of period $ 11 $ 12 $ 12 $ 13 Bad debt expense 4 2 5 4 Net write-offs (3) (2) (5) (5) End of period $ 12 $ 12 $ 12 $ 12 Ameren Illinois: (b) Beginning of period $ 26 $ 22 $ 18 $ 18 Bad debt expense 2 11 11 19 Charged to other accounts (a) 1 1 4 1 Net write-offs (4) (7) (8) (11) End of period $ 25 $ 27 $ 25 $ 27 (a) Amounts associated with the allowance for doubtful accounts related to receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. (b) 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. The table above does not include the impact related to the riders. Supplemental Cash Flow Information The following table provides noncash financing and investing activity excluded from the statements of cash flows for the six months ended June 30, 2024 and 2023: June 30, 2024 June 30, 2023 Ameren Ameren Ameren Ameren Ameren Ameren Investing: Accrued capital expenditures, including nuclear fuel expenditures $ 380 $ 232 $ 134 $ 325 $ 132 $ 173 Net realized and unrealized gain – nuclear decommissioning trust fund 103 103 — 105 105 — Return of investment in industrial development revenue bonds (a) — — — 240 240 — Financing: Issuance of common stock for stock-based compensation $ 16 $ — $ — $ 37 $ — $ — Issuance of common stock under the DRPlus 7 — — 7 — — Termination of a financing obligation (a) — — — 240 240 — (a) In January 2023, Ameren Missouri and Audrain County mutually agreed to terminate a financing obligation agreement related to the CT energy center in Audrain County, which was scheduled to expire in December 2023. No cash was exchanged in connection with the termination of the agreement as the $240 million principal amount of the financing obligation due from Ameren Missouri was equal to the amount of bond service payments due to Ameren Missouri. Asset Retirement Obligations The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the six months ended June 30, 2024: Ameren Ameren Ameren Balance at December 31, 2023 $ 787 (a) $ 4 (b) $ 791 (a) Liabilities incurred 7 (c) — 7 (c) Liabilities settled (4) (1) (5) Accretion 17 (d) — 17 (d) Balance at June 30, 2024 $ 807 (a) $ 3 (b) $ 810 (a) (a) Balance included $19 million in “Other current liabilities” on the balance sheet as of both June 30, 2024, and December 31, 2023. (b) Included in “Other deferred credits and liabilities” on the balance sheet. (c) In June 2024, Ameren and Ameren Missouri recorded an ARO related to the decommissioning for the Cass County Solar Project. In addition, as a result of the 2024 CCR Rule, Ameren and Ameren Missouri recorded an immaterial increase to their AROs associated with CCR storage facilities. See Note 9 – Commitments and Contingencies for additional information. (d) Accretion expense attributable to Ameren Missouri was recorded as a decrease to regulatory liabilities. Stock-based Compensation In the first quarter of 2024, Ameren granted 359,133 performance share units with a grant date fair value of $21 million and 153,887 restricted share units with a grant date fair value of $11 million. Awards vest approximately 3 years after the grant date based on continued employment 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 (307,816 performance share units) or clean energy transition targets (51,317 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 six months ended June 30, 2024 and 2023, excess tax benefits (deficiencies) associated with the settlement of stock-based compensation awards increased income tax expense by $1 million and reduced income tax expense by $6 million, respectively. Deferred Compensation At June 30, 2024, and December 31, 2023, the present value of benefits to be paid for deferred compensation obligations was $80 million and $85 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. Operating Revenues As of June 30, 2024 and 2023, 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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren Missouri $ 41 $ 39 $ 76 $ 73 Ameren Illinois 28 26 65 63 Ameren $ 69 $ 65 $ 141 $ 136 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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Weighted-average Common Shares Outstanding – Basic 266.7 262.6 266.5 262.4 Assumed settlement of performance share units and restricted stock units 0.1 0.6 0.3 0.8 Weighted-average Common Shares Outstanding – Diluted (a) 266.8 263.2 266.8 263.2 (a) There was an immaterial number of anti-dilutive performance share units excluded from the earnings per diluted share calculations for the three and six months ended June 30, 2024 and 2023. The outstanding forward sale agreements as of June 30, 2024 and 2023, were anti-dilutive for the three and six months ended June 30, 2024 and 2023, and were excluded from the earnings per diluted share calculation as calculated using the treasury stock method. For additional information about the outstanding forward sale agreements, see Note 4 – Long-term Debt and Equity Financings. |
Segment Information
Segment Information | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023. 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 2024: External revenues $ 879 $ 509 $ 148 $ 157 $ — $ — $ 1,693 Intersegment revenues 9 — — 34 — (43) — Net income (loss) attributable to Ameren common shareholders 128 61 6 79 (a) (16) — 258 Capital expenditures 638 132 59 175 2 (4) 1,002 Three Months 2023: External revenues $ 933 $ 540 $ 152 $ 135 $ — $ — $ 1,760 Intersegment revenues 8 — — 26 — (34) — Net income (loss) attributable to Ameren common shareholders 102 66 11 72 (a) (14) — 237 Capital expenditures 433 180 90 197 2 (11) 891 Six Months 2024: External revenues $ 1,647 $ 1,015 $ 539 $ 308 $ — $ — $ 3,509 Intersegment revenues 16 — — 68 — (84) — Net income (loss) attributable to Ameren common shareholders 153 117 112 151 (a) (14) — 519 Capital expenditures 1,104 316 119 341 4 8 1,892 Six Months 2023: External revenues $ 1,846 $ 1,164 $ 543 $ 269 $ — $ — $ 3,822 Intersegment revenues 18 — — 55 — (73) — Net income attributable to Ameren common shareholders 130 127 98 143 (a) 3 — 501 Capital expenditures 914 350 141 410 5 2 1,822 (a) Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent). Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2024: External revenues $ 509 $ 148 $ 109 $ — $ 766 Intersegment revenues — — 27 (27) — Net income available to common shareholder 61 6 57 — 124 Capital expenditures 132 59 153 — 344 Three Months 2023: External revenues $ 540 $ 152 $ 87 $ — $ 779 Intersegment revenues — — 26 (26) — Net income available to common shareholder 66 11 52 — 129 Capital expenditures 180 90 167 — 437 Six Months 2024: External revenues $ 1,015 $ 539 $ 212 $ — $ 1,766 Intersegment revenues — — 55 (55) — Net income available to common shareholder 117 112 110 — 339 Capital expenditures 316 119 282 — 717 Six Months 2023: External revenues $ 1,164 $ 543 $ 173 $ — $ 1,880 Intersegment revenues — — 54 (54) — Net income available to common shareholder 127 98 102 — 327 Capital expenditures 350 141 353 — 844 The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and six months ended June 30, 2024 and 2023. 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, off-system sales, and capacity revenues. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2024: Residential $ 395 $ 311 $ — $ — $ — $ 706 Commercial 324 163 — — — 487 Industrial 77 47 — — — 124 Other 68 (12) (a) — 191 (43) 204 Total electric revenues $ 864 $ 509 $ — $ 191 $ (43) $ 1,521 Residential $ 13 $ — $ 102 $ — $ — $ 115 Commercial 5 — 24 — — 29 Industrial 1 — 1 — — 2 Other 5 — 21 — — 26 Total natural gas revenues $ 24 $ — $ 148 $ — $ — $ 172 Total revenues (b) $ 888 $ 509 $ 148 $ 191 $ (43) $ 1,693 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2023: Residential $ 360 $ 337 $ — $ — $ — $ 697 Commercial 311 193 — — — 504 Industrial 75 48 — — — 123 Other 172 (38) (a) — 161 (34) 261 Total electric revenues $ 918 $ 540 $ — $ 161 $ (34) $ 1,585 Residential $ 13 $ — $ 98 $ — $ — $ 111 Commercial 6 — 25 — — 31 Industrial 1 — 2 — — 3 Other 3 — 27 — — 30 Total natural gas revenues $ 23 $ — $ 152 $ — $ — $ 175 Total revenues (b) $ 941 $ 540 $ 152 $ 161 $ (34) $ 1,760 Six Months 2024: Residential $ 736 $ 608 $ — $ — $ — $ 1,344 Commercial 583 328 — — — 911 Industrial 138 92 — — — 230 Other 121 (13) (a) — 376 (84) 400 Total electric revenues $ 1,578 $ 1,015 $ — $ 376 $ (84) $ 2,885 Residential $ 53 $ — $ 389 $ — $ — $ 442 Commercial 21 — 92 — — 113 Industrial 3 — 5 — — 8 Other 8 — 53 — — 61 Total natural gas revenues $ 85 $ — $ 539 $ — $ — $ 624 Total revenues (b) $ 1,663 $ 1,015 $ 539 $ 376 $ (84) $ 3,509 Six Months 2023: Residential $ 684 $ 719 $ — $ — $ — $ 1,403 Commercial 558 393 — — — 951 Industrial 136 96 — — — 232 Other 381 (44) (a) — 324 (72) 589 Total electric revenues $ 1,759 $ 1,164 $ — $ 324 $ (72) $ 3,175 Residential $ 65 $ — $ 394 $ — $ — $ 459 Commercial 29 — 102 — — 131 Industrial 3 — 9 — — 12 Other 8 — 38 — (1) 45 Total natural gas revenues $ 105 $ — $ 543 $ — $ (1) $ 647 Total revenues (b) $ 1,864 $ 1,164 $ 543 $ 324 $ (73) $ 3,822 (a) Includes over-recoveries of various riders. (b) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and six months ended June 30, 2024 and 2023: Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Ameren Three Months 2024: Revenues from alternative revenue programs $ (1) $ 22 $ — $ 4 $ 25 Other revenues not from contracts with customers 1 1 1 — 3 Three Months 2023: Revenues from alternative revenue programs $ — $ 60 $ 9 $ 5 $ 74 Other revenues not from contracts with customers (2) (a) 2 1 — 1 (a) Six Months 2024: Revenues from alternative revenue programs $ (7) $ 61 $ 19 $ 13 $ 86 Other revenues not from contracts with customers 2 3 2 — 7 Six Months 2023: Revenues from alternative revenue programs $ (2) $ 124 $ 37 $ 13 $ 172 Other revenues not from contracts with customers (8) (a) 4 2 — (2) (a) (a) Includes net realized losses on derivative power contracts. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2024: Residential $ 311 $ 102 $ — $ — $ 413 Commercial 163 24 — — 187 Industrial 47 1 — — 48 Other (12) (a) 21 136 (27) 118 Total revenues (b) $ 509 $ 148 $ 136 $ (27) $ 766 Three Months 2023: Residential $ 337 $ 98 $ — $ — $ 435 Commercial 193 25 — — 218 Industrial 48 2 — — 50 Other (38) (a) 27 113 (26) 76 Total revenues (b) $ 540 $ 152 $ 113 $ (26) $ 779 Six Months 2024: Residential $ 608 $ 389 $ — $ — $ 997 Commercial 328 92 — — 420 Industrial 92 5 — — 97 Other (13) (a) 53 267 (55) 252 Total revenues (b) $ 1,015 $ 539 $ 267 $ (55) $ 1,766 Six Months 2023: Residential $ 719 $ 394 $ — $ — $ 1,113 Commercial 393 102 — — 495 Industrial 96 9 — — 105 Other (44) (a) 38 227 (54) 167 Total revenues (b) $ 1,164 $ 543 $ 227 $ (54) $ 1,880 (a) Includes over-recoveries of various riders. (b) 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 six months ended June 30, 2024 and 2023: Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois Three Months 2024: Revenues from alternative revenue programs $ 22 $ — $ 2 $ 24 Other revenues not from contracts with customers 1 1 — 2 Three Months 2023: Revenues from alternative revenue programs $ 60 $ 9 $ 3 $ 72 Other revenues not from contracts with customers 2 1 — 3 Six Months 2024: Revenues from alternative revenue programs $ 61 $ 19 $ 10 $ 90 Other revenues not from contracts with customers 3 2 — 5 Six Months 2023: Revenues from alternative revenue programs $ 124 $ 37 $ 10 $ 171 Other revenues not from contracts with customers 4 2 — 6 |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended | 6 Months Ended |
Jun. 30, 2024 shares | Jun. 30, 2024 shares | |
Trading Arrangements, by Individual | ||
Non-Rule 10b5-1 Arrangement Adopted | false | |
Rule 10b5-1 Arrangement Terminated | false | |
Non-Rule 10b5-1 Arrangement Terminated | false | |
Michael L. Moehn [Member] | ||
Trading Arrangements, by Individual | ||
Material Terms of Trading Arrangement | On May 21, 2024, Michael L. Moehn, Senior Executive Vice President and Chief Financial Officer of Ameren, adopted a Rule 10b5-1 trading arrangement. Mr. Moehn's Rule 10b5-1 trading arrangement provides for the sale of an aggregate 26,000 shares to be sold in four equal quarterly installments between August 2024 and July 2025. Mr. Moehn’s' Rule 10b5-1 trading arrangement will terminate on the earlier of: (i) July 31, 2025; (ii) execution of all trades or expiration of all orders relating to such trades under the Rule 10b5-1 trading arrangement; or (iii) such date as the Rule 10b5-1 trading arrangement is otherwise terminated according to its terms. | |
Name | Michael L. Moehn | |
Title | Senior Executive Vice President and Chief Financial Officer of Ameren | |
Rule 10b5-1 Arrangement Adopted | true | |
Adoption Date | May 21, 2024 | |
Arrangement Duration | 436 days | |
Aggregate Available | 26,000 | 26,000 |
Shawn E. Schukar [Member] | ||
Trading Arrangements, by Individual | ||
Material Terms of Trading Arrangement | On May 22, 2024, Shawn E. Schukar, Chairman and President of ATXI, adopted a Rule 10b5-1 trading arrangement. Mr. Schukar's Rule 10b5-1 trading arrangement provides for the sale of 100% of any net shares of Ameren common stock received, after tax withholding, in connection with certain previously awarded restricted stock units and performance share units that will vest upon payment in March 2025 and March 2026. The estimated maximum number of shares to be sold pursuant to the Rule 10b5-1 trading arrangement is 10,170 shares. The actual number of shares sold pursuant to the Rule 10b5-1 trading arrangement will depend on the actual number of shares earned pursuant to the awards, which is generally dependent on the Company's achievement of certain performance measures, the actual dividends paid by the Company during the applicable vesting periods, and Mr. Schukar's continued employment and individual performance during the applicable vesting periods. Mr. Schukar's Rule 10b5-1 trading arrangement will terminate on the earlier of: (i) March 31, 2026; (ii) execution of all trades or expiration of all orders relating to such trades under the Rule 10b5-1 trading arrangement; or (iii) such date as the Rule 10b5-1 trading arrangement is otherwise terminated according to its terms. | |
Name | Shawn E. Schukar | |
Title | Chairman and President of ATXI | |
Rule 10b5-1 Arrangement Adopted | true | |
Adoption Date | May 22, 2024 | |
Arrangement Duration | 678 days | |
Aggregate Available | 10,170 | 10,170 |
Mark C. Lindgren [Member] | ||
Trading Arrangements, by Individual | ||
Material Terms of Trading Arrangement | On June 6, 2024, Mark C. Lindgren, Executive Vice President, Corporate Communications, and Chief Human Resources Officer of Ameren Services Company, adopted a Rule 10b5-1 trading arrangement. Mr. Lindgren's Rule 10b5-1 trading arrangement provides for the sale of 50% of any net shares of Ameren common stock received, after tax withholding, in connection with certain previously awarded restricted stock units and performance share units that will vest upon payment in March 2025 and March 2026. The estimated maximum number of shares to be sold pursuant to the Rule 10b5-1 trading arrangement is 3,841 shares. The actual number of shares sold pursuant to the Rule 10b5-1 trading arrangement will depend on the actual number of shares earned pursuant to the awards, which is generally dependent on the Company's achievement of certain performance measures, the actual dividends paid by the Company during the applicable vesting periods, and Mr. Lindgren's continued employment and individual performance during the applicable vesting periods. Mr. Lindgren's Rule 10b5-1 trading arrangement will terminate on the earlier of: (i) March 31, 2026; (ii) execution of all trades or expiration of all orders relating to such trades under the Rule 10b5-1 trading arrangement; or (iii) such date as the Rule 10b5-1 trading arrangement is otherwise terminated according to its terms. | |
Name | Mark C. Lindgren | |
Title | Executive Vice President, Corporate Communications, and Chief Human Resources Officer of Ameren Services Company | |
Rule 10b5-1 Arrangement Adopted | true | |
Adoption Date | June 6, 2024 | |
Arrangement Duration | 663 days | |
Aggregate Available | 3,841 | 3,841 |
Summary Of Significant Accoun_2
Summary Of Significant Accounting Policies (Policies) | 6 Months Ended |
Jun. 30, 2024 | |
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 also 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 statement of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the 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 June 30, 2024, and December 31, 2023, Ameren had unconsolidated variable interests in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $75 million and $73 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 June 30, 2024, Ameren’s maximum exposure to loss related to these variable interests is limited to its investment of $75 million plus associated outstanding funding commitments of $12 million. |
Life Insurance, Corporate Or Bank Owned | COLI |
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. 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. |
Deferred Compensation | Deferred Compensation At June 30, 2024, and December 31, 2023, the present value of benefits to be paid for deferred compensation obligations was $80 million and $85 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 June 30, 2024 and 2023, 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 Taxes |
Rate and Regulatory Matters (Ta
Rate and Regulatory Matters (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Regulated Operations [Abstract] | |
Schedule of Generation Facilities | The following table provides information with respect to each agreement: Agreement type Facility size Status of MoPSC CCN Status of FERC approval of acquisition Anticipated in-service date (a) Huck Finn Solar Project (b)(c) Build-transfer 200-MW Approved February 2023 Received March 2023 Fourth quarter 2024 Boomtown Solar Project (c)(d) Build-transfer 150-MW Approved April 2023 Received October 2023 Fourth quarter 2024 (e) Cass County Solar Project (d) Development-transfer (f) 150-MW Approved June 2024 Not applicable Fourth quarter 2024 Vandalia Solar Project (c)(g) Self-build 50-MW Approved March 2024 Not applicable Fourth quarter 2025 Bowling Green Solar Project (c)(g) Self-build 50-MW Approved March 2024 Not applicable First quarter 2026 Split Rail Solar Project (g) Build-transfer 300-MW Approved March 2024 Requested July 2024 Mid-2026 Castle Bluff Natural Gas Project Self-build 800-MW Filed June 2024 Not applicable Fourth quarter 2027 (a) Anticipated in-service dates are dependent on the timing of regulatory approvals and construction completion, among other things. (b) The Huck Finn Solar Project is expected to support Ameren Missouri’s compliance with the state of Missouri’s renewable energy standard. Investments in the project will be eligible for recovery under the RESRAM. Ameren Missouri expects to close on the acquisition of the Huck Finn Solar Project in the fourth quarter of 2024. (c) These projects collectively represent approximately $0.85 billion of expected capital expenditures. (d) The Boomtown and Cass County solar projects are expected to support Ameren Missouri’s transition to renewable energy generation and serve customers under the Renewable Solutions Program. (e) Ameren Missouri expects to close on the acquisition of the Boomtown Solar Project in August 2024. (f) In June 2024, Ameren Missouri acquired the Cass County Solar Project, which includes solar panels, project design, land rights, and engineering, procurement, and construction agreements, for approximately $250 million and took over construction management of the project. (g) These solar projects are expected to support Ameren Missouri’s transition to renewable energy generation. |
Schedule of MYRP details | The following table presents the approved revenue requirements and average annual rate base in the ICC’s June 2024 rehearing order, as well as the proposed revenue requirements and average annual rate base in Ameren Illinois’ July 2024 revised MYRP and the ICC staff’s July 2024 revised MYRP recommendation: Year Revenue Requirement (in millions) Average Annual Rate Base (in billions) ICC’s June 2024 Rehearing Order (a) : 2024 $1,196 $4.0 2025 $1,282 $4.3 2026 $1,350 $4.5 2027 $1,397 $4.7 Ameren Illinois’ July 2024 Revised MYRP (a) : 2024 $1,215 $4.3 2025 $1,300 $4.5 2026 $1,386 $4.8 2027 $1,446 $5.0 ICC Staff’s July 2024 Revised MYRP (a) : 2024 $1,201 $4.2 2025 $1,281 $4.4 2026 $1,361 $4.6 2027 $1,414 $4.8 (a) Based on an allowed ROE of 8.72% and a capital structure composed of 50% common equity. The ROE is under appeal, as discussed above. |
Short-Term Debt and Liquidity (
Short-Term Debt and Liquidity (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Debt Disclosure [Abstract] | |
Schedule of Short-term Debt | The following table presents commercial paper outstanding, net of issuance discounts, as of June 30, 2024, and December 31, 2023. There were no borrowings outstanding under the Credit Agreements as of June 30, 2024, or December 31, 2023. June 30, 2024 December 31, 2023 Ameren (parent) $ 301 $ — Ameren Missouri 390 170 Ameren Illinois — 366 Ameren consolidated $ 691 $ 536 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 six months ended June 30, 2024 and 2023: Ameren Ameren Ameren Ameren 2024 Average daily amount outstanding $ 84 $ 109 $ 385 $ 578 Weighted-average interest rate 5.55 % 5.53 % 5.57 % 5.56 % Peak amount outstanding during period (a) $ 301 $ 509 $ 694 $ 1,084 Peak interest rate 5.60 % 5.68 % 5.68 % 5.68 % 2023 Average daily amount outstanding $ 595 $ 343 $ 230 $ 1,168 Weighted-average interest rate 5.14 % 5.04 % 5.10 % 5.10 % Peak amount outstanding during period (a) $ 841 $ 592 $ 450 $ 1,381 Peak interest rate 5.55 % 5.55 % 5.60 % 5.60 % (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 amount for the period. |
Other Income, Net (Tables)
Other Income, Net (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren: Allowance for equity funds used during construction $ 16 $ 14 $ 25 $ 23 Other interest income 13 9 21 17 Non-service cost components of net periodic benefit income (a) 76 63 152 127 Miscellaneous income 4 2 6 4 Earnings related to equity method investments 1 — 1 2 Donations (2) (2) (4) (4) Miscellaneous expense (5) (4) (9) (9) Total Other Income, Net $ 103 $ 82 $ 192 $ 160 Ameren Missouri: Allowance for equity funds used during construction $ 14 $ 8 $ 23 $ 12 Other interest income 3 2 5 6 Non-service cost components of net periodic benefit income (a) 35 14 69 28 Miscellaneous income — 1 2 2 Donations (1) (1) (2) (2) Miscellaneous expense (2) (2) (4) (5) Total Other Income, Net $ 49 $ 22 $ 93 $ 41 Ameren Illinois: Allowance for equity funds used during construction $ 2 $ 6 $ 2 $ 10 Other interest income 9 6 15 10 Non-service cost components of net periodic benefit income 26 31 53 62 Miscellaneous income 2 1 3 2 Donations (1) (1) (2) (2) Miscellaneous expense (1) (2) (3) (4) Total Other Income, Net $ 37 $ 41 $ 68 $ 78 (a) For the three and six months ended June 30, 2024, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $(11) million and $(20) 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 $17 million and $34 million, respectively, for the three and six months ended June 30, 2023. See Note 11 – Retirement Benefits for additional information. |
Derivative Financial Instrume_2
Derivative Financial Instruments (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Open Gross Derivative Volumes By Commodity Type | The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of June 30, 2024, and December 31, 2023. As of June 30, 2024, these contracts extended through October 2027, October 2029 and May 2032 for fuel oils, natural gas and power, respectively. Quantity (in millions) June 30, 2024 December 31, 2023 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) 20 — 20 17 — 17 Natural gas (in mmbtu) 52 221 273 53 218 271 Power (in MWhs) — 5 5 — 5 5 Uranium (pounds in thousands) — — — 186 — 186 |
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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Balance Sheet Location Ameren Ameren Ameren Ameren Ameren Ameren Fuel oils Other current assets $ 2 $ — $ 2 $ 2 $ — $ 2 Natural gas Other current assets 1 3 4 — — — Other assets 2 1 3 3 3 6 Power Other current assets 15 — 15 5 — 5 Uranium Other current assets — — — 9 — 9 Total assets $ 20 $ 4 $ 24 $ 19 $ 3 $ 22 Fuel oils Other current liabilities $ 1 $ — $ 1 $ 1 $ — $ 1 Other deferred credits and liabilities — — — 1 — 1 Natural gas Other current liabilities 9 33 42 12 45 57 Other deferred credits and liabilities 8 28 36 10 30 40 Power Other current liabilities 1 11 12 1 12 13 Other deferred credits and liabilities — 50 50 — 56 56 Total liabilities $ 19 $ 122 $ 141 $ 25 $ 143 $ 168 |
Offsetting Assets and Liabilities | Th e following table p rovides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of June 30, 2024, and December 31, 2023: Gross Amounts Not Offset in the Balance Sheet Commodity Contracts Eligible to be Offset Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted (a) Net Amount June 30, 2024 Assets: Ameren Missouri $ 20 $ 5 $ — $ 15 Ameren Illinois 4 2 — 2 Ameren $ 24 $ 7 $ — $ 17 Liabilities: Ameren Missouri $ 19 $ 5 $ — $ 14 Ameren Illinois 122 2 — 120 Ameren $ 141 $ 7 $ — $ 134 December 31, 2023 Assets: Ameren Missouri $ 19 $ 6 $ — $ 13 Ameren Illinois 3 1 — 2 Ameren $ 22 $ 7 $ — $ 15 Liabilities: Ameren Missouri $ 25 $ 6 $ — $ 19 Ameren Illinois 143 1 6 136 Ameren $ 168 $ 7 $ 6 $ 155 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. |
Derivative Instruments With Credit Risk-Related Contingent Features | The following table presents, as of June 30, 2024, the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require: Aggregate Fair Value of Derivative Liabilities (a) Cash Potential Aggregate Amount of Additional Collateral Required (b) Ameren Missouri $ 19 $ — $ 13 Ameren Illinois 61 — 59 Ameren $ 80 $ — $ 72 (a) Before consideration of master netting arrangements or similar agreements. (b) As collateral requirements with certain counterparties are based on master netting arrangements or similar agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such arrangements. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets: Ameren Missouri Derivative assets – commodity contracts: Fuel oils $ 1 $ — $ 1 $ 2 $ 2 $ — $ — $ 2 Natural gas — 3 — 3 — 3 — 3 Power — — 15 15 — — 5 5 Uranium — — — — — — 9 9 Total derivative assets – commodity contracts $ 1 $ 3 $ 16 $ 20 $ 2 $ 3 $ 14 $ 19 Nuclear decommissioning trust fund: Equity securities: U.S. large capitalization $ 842 $ — $ — $ 842 $ 787 $ — $ — $ 787 Debt securities: U.S. Treasury and agency securities — 178 — 178 — 150 — 150 Corporate bonds — 154 — 154 — 136 — 136 Other — 82 — 82 — 68 — 68 Total nuclear decommissioning trust fund $ 842 $ 414 $ — $ 1,256 (a) $ 787 $ 354 $ — $ 1,141 (a) Total Ameren Missouri $ 843 $ 417 $ 16 $ 1,276 $ 789 $ 357 $ 14 $ 1,160 Ameren Illinois Derivative assets – commodity contracts: Natural gas — 1 3 4 — 1 2 3 Total Ameren Illinois $ — $ 1 $ 3 $ 4 $ — $ 1 $ 2 $ 3 Ameren Derivative assets – commodity contracts (b) $ 1 $ 4 $ 19 $ 24 $ 2 $ 4 $ 16 $ 22 Nuclear decommissioning trust fund (c) 842 414 — 1,256 (a) 787 354 — 1,141 (a) Total Ameren $ 843 $ 418 $ 19 $ 1,280 $ 789 $ 358 $ 16 $ 1,163 Liabilities: Ameren Missouri Derivative liabilities – commodity contracts: Fuel oils $ 1 $ — $ — $ 1 $ 2 $ — $ — $ 2 Natural gas — 16 1 17 — 19 3 22 Power — — 1 1 — — 1 1 Total Ameren Missouri $ 1 $ 16 $ 2 $ 19 $ 2 $ 19 $ 4 $ 25 Ameren Illinois Derivative liabilities – commodity contracts: Natural gas $ 2 $ 52 $ 7 $ 61 $ 4 $ 60 $ 11 $ 75 Power — — 61 61 — — 68 68 Total Ameren Illinois $ 2 $ 52 $ 68 $ 122 $ 4 $ 60 $ 79 $ 143 Ameren Derivative liabilities – commodity contracts (b) $ 3 $ 68 $ 70 $ 141 $ 6 $ 79 $ 83 $ 168 (a) Balance excludes $10 million and $9 million of cash and cash equivalents, receivables, payables, and accrued income, net, for June 30, 2024, and December 31, 2023, 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 six months ended June 30, 2024 and 2023: 2024 2023 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren For the three months ended June 30: Beginning balance at April 1 $ 2 $ (54) $ (52) $ 5 $ (52) $ (47) Realized and unrealized gains/(losses) included in regulatory assets/liabilities 15 (12) 3 14 (20) (6) Settlements (3) 5 2 (5) 4 (1) Ending balance at June 30 $ 14 $ (61) $ (47) $ 14 $ (68) $ (54) Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ 14 $ (12) $ 2 $ 14 $ (20) $ (6) For the six months ended June 30: Beginning balance at January 1 $ 4 $ (68) $ (64) $ 12 $ (33) $ (21) Realized and unrealized gains/(losses) included in regulatory assets/liabilities 14 (2) 12 8 (41) (33) Settlements (4) 9 5 (6) 6 — Ending balance at June 30 $ 14 $ (61) $ (47) $ 14 $ (68) $ (54) Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ 14 $ — $ 14 $ 14 $ (35) $ (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 June 30, 2024, and December 31, 2023: Fair Value Weighted Average (b) Commodity Assets Liabilities Valuation Technique(s) Unobservable Input (a) Range 2024 Power (c) $ 15 $ (62) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 33 – 70 43 Nodal basis ($/MWh) (10) – (1) (5) 2023 Power (c) $ 5 $ (69) Discounted cash flow Average forward peak and off-peak pricing – forwards/swaps ($/MWh) 31 – 65 43 Nodal basis ($/MWh) (8) – (1) (5) (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 use visible forward prices adjusted for nodal-to-hub basis differentials. |
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 long-term debt (including current portion) disclosed, but not recorded, at fair value as of June 30, 2024, and December 31, 2023: Long-Term Debt (Including Current Portion): Carrying Amount (a) Fair Value Level 2 Level 3 Total June 30, 2024 Ameren $ 17,079 $ 14,990 $ 460 (b) $ 15,450 Ameren Missouri 6,830 6,069 — 6,069 Ameren Illinois 5,851 5,251 — 5,251 December 31, 2023 Ameren $ 15,970 $ 14,366 $ 467 (b) $ 14,833 Ameren Missouri 6,341 5,800 — 5,800 Ameren Illinois 5,232 4,867 — 4,867 (a) Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $124 million, $53 million, and $52 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of June 30, 2024. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $111 million, $45 million, and $47 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2023. (b) The Level 3 fair value amount consists of ATXI’s senior unsecured notes. |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois Income taxes payable to parent (a) $ — $ 44 $ — $ 2 Income taxes receivable from parent (b) 54 — 56 22 (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 six months ended June 30, 2024 and 2023: Three Months Six Months Agreement Income Statement Ameren Ameren Ameren Ameren Ameren Missouri power supply Operating Revenues 2024 $ (b) $ (a) $ (b) $ (a) agreements with Ameren Illinois 2023 (b) (a) (b) (a) Ameren Missouri and Ameren Illinois Operating Revenues 2024 $ 8 $ (b) $ 15 $ (b) rent and facility services 2023 8 (b) 18 (b) Ameren Missouri and Ameren Illinois miscellaneous Operating Revenues 2024 $ 1 $ (b) $ 1 $ 1 support services 2023 (b) (b) (b) (b) Total Operating Revenues 2024 $ 9 $ (b) $ 16 $ 1 2023 8 (b) 18 (b) Ameren Illinois power supply Purchased Power 2024 $ (a) $ (b) $ (a) $ (b) agreements with Ameren Missouri 2023 (a) (b) (a) (b) Ameren Missouri and Ameren Illinois Purchased Power 2024 $ 2 $ 1 $ 4 $ 1 transmission services from ATXI 2023 1 (b) 1 (b) Total Purchased Power 2024 $ 2 $ 1 $ 4 $ 1 2023 1 (b) 1 (b) Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2024 $ (b) $ (b) $ (b) $ (b) rent and facility services 2023 (b) (b) (b) 2 Ameren Services support services Other Operations and Maintenance 2024 $ 43 $ 40 $ 81 $ 77 agreement 2023 35 33 70 68 Total Other Operations and 2024 $ 43 $ 40 $ 81 $ 77 Maintenance 2023 35 33 70 70 Money pool interest (Interest Charges)/Other Income, Net 2024 $ (b) $ (b) $ (3) $ (2) 2023 (b) (b) (b) (b) (a) Not applicable. (b) Amount less than $1 million. |
Callaway Energy Center (Tables)
Callaway Energy Center (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 April 1, 2024: Type and Source of Coverage Most Recent Maximum Coverages Maximum Assessments Public liability and nuclear worker liability: American Nuclear Insurers January 1, 2024 $ 500 $ — Pool participation (a) 15,763 (a) 166 (b) $ 16,263 (c) $ 166 Property damage: NEIL and EMANI April 1, 2024 $ 3,200 (d) $ 28 (e) Accidental outage: NEIL April 1, 2024 $ 490 (f) $ 11 (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 $500 million in the event of an incident at any licensed United States commercial reactor, payable at $24.7 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 $0.7 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 $291 million. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2024 2023 2024 2023 2024 2023 2024 2023 Service cost (a) $ 23 $ 23 $ 44 $ 46 $ 3 $ 3 $ 6 $ 6 Non-service cost components: Interest cost 56 56 111 111 11 12 22 23 Expected return on plan assets (b) (82) (84) (164) (167) (23) (23) (46) (46) Amortization of (b) : Prior service benefit — — — — (1) (1) (2) (2) Actuarial (gain) (16) (28) (33) (57) (10) (12) (20) (23) Total non-service cost components (c) $ (42) $ (56) $ (86) $ (113) $ (23) $ (24) $ (46) $ (48) Net periodic benefit income (d) $ (19) $ (33) $ (42) $ (67) $ (20) $ (21) $ (40) $ (42) (a) Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income. (b) Prior service benefit is amortized on a straight-line basis over the average future service of active participants benefiting under a plan amendment. Net actuarial gains or losses related to the net benefit obligation subject to amortization are amortized on a straight-line basis over 10 years. The difference between the actual and expected return on plan assets is amortized over 4 years. (c) Non-service cost components are reflected in “Other Income, Net” on Ameren’s consolidated statement of income. See Note 5 – Other Income, Net for additional information. (d) Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) 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 six months ended June 30, 2024 and 2023: Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2024 2023 2024 2023 2024 2023 2024 2023 Ameren Missouri (a) $ (10) $ (17) $ (22) $ (35) $ (7) $ (7) $ (14) $ (15) Ameren Illinois (8) (13) (17) (27) (13) (14) (26) (27) Other (1) (3) (3) (5) — — — — Ameren (a) $ (19) $ (33) $ (42) $ (67) $ (20) $ (21) $ (40) $ (42) (a) Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) incurred by Ameren Missouri under GAAP and the level of such costs included in rates. |
Income Taxes (Tables)
Income Taxes (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023: Ameren Ameren Missouri Ameren Illinois 2024 2023 2024 2023 2024 2023 Three Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of excess deferred taxes (a) (8) (7) (14) (15) (4) (2) Renewable and other tax credits (b) (4) (5) (8) (10) — — State tax 5 5 3 3 7 7 Depreciation differences (1) — (1) — — (1) Effective income tax rate 13 % 14 % 1 % (1) % 24 % 25 % Six Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 % Increases (decreases) from: Amortization of excess deferred taxes (a) (8) (8) (14) (15) (4) (2) Renewable and other tax credits (b) (4) (4) (8) (10) — — State tax 5 5 3 3 7 7 Depreciation differences — — — — — (1) Other permanent items — (1) — — — — Effective income tax rate 14 % 13 % 2 % (1) % 24 % 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) |
Supplemental Information (Table
Supplemental Information (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024, and December 31, 2023: June 30, 2024 December 31, 2023 Ameren Ameren Ameren Ameren Ameren Ameren “Cash and cash equivalents” $ 19 $ — $ 6 $ 25 $ — $ — Restricted cash included in “Other current assets” 18 7 7 13 5 5 Restricted cash included in “Other assets” 260 — 260 229 — 229 Restricted cash included in “Nuclear decommissioning trust fund” 4 4 — 5 5 — Total cash, cash equivalents, and restricted cash $ 301 $ 11 $ 273 $ 272 $ 10 $ 234 |
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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren: Beginning of period $ 37 $ 34 $ 30 $ 31 Bad debt expense 6 13 16 23 Charged to other accounts (a) 1 1 4 1 Net write-offs (7) (9) (13) (16) End of period $ 37 $ 39 $ 37 $ 39 Ameren Missouri: Beginning of period $ 11 $ 12 $ 12 $ 13 Bad debt expense 4 2 5 4 Net write-offs (3) (2) (5) (5) End of period $ 12 $ 12 $ 12 $ 12 Ameren Illinois: (b) Beginning of period $ 26 $ 22 $ 18 $ 18 Bad debt expense 2 11 11 19 Charged to other accounts (a) 1 1 4 1 Net write-offs (4) (7) (8) (11) End of period $ 25 $ 27 $ 25 $ 27 (a) Amounts associated with the allowance for doubtful accounts related to receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. (b) 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. The table above does not include the impact related to the riders. |
Schedule of Cash Flow, Supplemental Disclosures | The following table provides noncash financing and investing activity excluded from the statements of cash flows for the six months ended June 30, 2024 and 2023: June 30, 2024 June 30, 2023 Ameren Ameren Ameren Ameren Ameren Ameren Investing: Accrued capital expenditures, including nuclear fuel expenditures $ 380 $ 232 $ 134 $ 325 $ 132 $ 173 Net realized and unrealized gain – nuclear decommissioning trust fund 103 103 — 105 105 — Return of investment in industrial development revenue bonds (a) — — — 240 240 — Financing: Issuance of common stock for stock-based compensation $ 16 $ — $ — $ 37 $ — $ — Issuance of common stock under the DRPlus 7 — — 7 — — Termination of a financing obligation (a) — — — 240 240 — (a) In January 2023, Ameren Missouri and Audrain County mutually agreed to terminate a financing obligation agreement related to the CT energy center in Audrain County, which was scheduled to expire in December 2023. No cash was exchanged in connection with the termination of the agreement as the $240 million principal amount of the financing obligation due from Ameren Missouri was equal to the amount of bond service payments due to Ameren Missouri. |
Asset Retirement Obligation Disclosure | The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the six months ended June 30, 2024: Ameren Ameren Ameren Balance at December 31, 2023 $ 787 (a) $ 4 (b) $ 791 (a) Liabilities incurred 7 (c) — 7 (c) Liabilities settled (4) (1) (5) Accretion 17 (d) — 17 (d) Balance at June 30, 2024 $ 807 (a) $ 3 (b) $ 810 (a) (a) Balance included $19 million in “Other current liabilities” on the balance sheet as of both June 30, 2024, and December 31, 2023. (b) Included in “Other deferred credits and liabilities” on the balance sheet. (c) In June 2024, Ameren and Ameren Missouri recorded an ARO related to the decommissioning for the Cass County Solar Project. In addition, as a result of the 2024 CCR Rule, Ameren and Ameren Missouri recorded an immaterial increase to their AROs associated with CCR storage facilities. See Note 9 – Commitments and Contingencies for additional information. (d) 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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Ameren Missouri $ 41 $ 39 $ 76 $ 73 Ameren Illinois 28 26 65 63 Ameren $ 69 $ 65 $ 141 $ 136 |
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 six months ended June 30, 2024 and 2023: Three Months Six Months 2024 2023 2024 2023 Weighted-average Common Shares Outstanding – Basic 266.7 262.6 266.5 262.4 Assumed settlement of performance share units and restricted stock units 0.1 0.6 0.3 0.8 Weighted-average Common Shares Outstanding – Diluted (a) 266.8 263.2 266.8 263.2 (a) There was an immaterial number of anti-dilutive performance share units excluded from the earnings per diluted share calculations for the three and six months ended June 30, 2024 and 2023. The outstanding forward sale agreements as of June 30, 2024 and 2023, were anti-dilutive for the three and six months ended June 30, 2024 and 2023, and were excluded from the earnings per diluted share calculation as calculated using the treasury stock method. For additional information about the outstanding forward sale agreements, see Note 4 – Long-term Debt and Equity Financings. |
Segment Information (Tables)
Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 six months ended June 30, 2024 and 2023. 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 2024: External revenues $ 879 $ 509 $ 148 $ 157 $ — $ — $ 1,693 Intersegment revenues 9 — — 34 — (43) — Net income (loss) attributable to Ameren common shareholders 128 61 6 79 (a) (16) — 258 Capital expenditures 638 132 59 175 2 (4) 1,002 Three Months 2023: External revenues $ 933 $ 540 $ 152 $ 135 $ — $ — $ 1,760 Intersegment revenues 8 — — 26 — (34) — Net income (loss) attributable to Ameren common shareholders 102 66 11 72 (a) (14) — 237 Capital expenditures 433 180 90 197 2 (11) 891 Six Months 2024: External revenues $ 1,647 $ 1,015 $ 539 $ 308 $ — $ — $ 3,509 Intersegment revenues 16 — — 68 — (84) — Net income (loss) attributable to Ameren common shareholders 153 117 112 151 (a) (14) — 519 Capital expenditures 1,104 316 119 341 4 8 1,892 Six Months 2023: External revenues $ 1,846 $ 1,164 $ 543 $ 269 $ — $ — $ 3,822 Intersegment revenues 18 — — 55 — (73) — Net income attributable to Ameren common shareholders 130 127 98 143 (a) 3 — 501 Capital expenditures 914 350 141 410 5 2 1,822 (a) Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent). Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2024: External revenues $ 509 $ 148 $ 109 $ — $ 766 Intersegment revenues — — 27 (27) — Net income available to common shareholder 61 6 57 — 124 Capital expenditures 132 59 153 — 344 Three Months 2023: External revenues $ 540 $ 152 $ 87 $ — $ 779 Intersegment revenues — — 26 (26) — Net income available to common shareholder 66 11 52 — 129 Capital expenditures 180 90 167 — 437 Six Months 2024: External revenues $ 1,015 $ 539 $ 212 $ — $ 1,766 Intersegment revenues — — 55 (55) — Net income available to common shareholder 117 112 110 — 339 Capital expenditures 316 119 282 — 717 Six Months 2023: External revenues $ 1,164 $ 543 $ 173 $ — $ 1,880 Intersegment revenues — — 54 (54) — Net income available to common shareholder 127 98 102 — 327 Capital expenditures 350 141 353 — 844 |
Disaggregation of Revenue | The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and six months ended June 30, 2024 and 2023. 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, off-system sales, and capacity revenues. Ameren Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2024: Residential $ 395 $ 311 $ — $ — $ — $ 706 Commercial 324 163 — — — 487 Industrial 77 47 — — — 124 Other 68 (12) (a) — 191 (43) 204 Total electric revenues $ 864 $ 509 $ — $ 191 $ (43) $ 1,521 Residential $ 13 $ — $ 102 $ — $ — $ 115 Commercial 5 — 24 — — 29 Industrial 1 — 1 — — 2 Other 5 — 21 — — 26 Total natural gas revenues $ 24 $ — $ 148 $ — $ — $ 172 Total revenues (b) $ 888 $ 509 $ 148 $ 191 $ (43) $ 1,693 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren Three Months 2023: Residential $ 360 $ 337 $ — $ — $ — $ 697 Commercial 311 193 — — — 504 Industrial 75 48 — — — 123 Other 172 (38) (a) — 161 (34) 261 Total electric revenues $ 918 $ 540 $ — $ 161 $ (34) $ 1,585 Residential $ 13 $ — $ 98 $ — $ — $ 111 Commercial 6 — 25 — — 31 Industrial 1 — 2 — — 3 Other 3 — 27 — — 30 Total natural gas revenues $ 23 $ — $ 152 $ — $ — $ 175 Total revenues (b) $ 941 $ 540 $ 152 $ 161 $ (34) $ 1,760 Six Months 2024: Residential $ 736 $ 608 $ — $ — $ — $ 1,344 Commercial 583 328 — — — 911 Industrial 138 92 — — — 230 Other 121 (13) (a) — 376 (84) 400 Total electric revenues $ 1,578 $ 1,015 $ — $ 376 $ (84) $ 2,885 Residential $ 53 $ — $ 389 $ — $ — $ 442 Commercial 21 — 92 — — 113 Industrial 3 — 5 — — 8 Other 8 — 53 — — 61 Total natural gas revenues $ 85 $ — $ 539 $ — $ — $ 624 Total revenues (b) $ 1,663 $ 1,015 $ 539 $ 376 $ (84) $ 3,509 Six Months 2023: Residential $ 684 $ 719 $ — $ — $ — $ 1,403 Commercial 558 393 — — — 951 Industrial 136 96 — — — 232 Other 381 (44) (a) — 324 (72) 589 Total electric revenues $ 1,759 $ 1,164 $ — $ 324 $ (72) $ 3,175 Residential $ 65 $ — $ 394 $ — $ — $ 459 Commercial 29 — 102 — — 131 Industrial 3 — 9 — — 12 Other 8 — 38 — (1) 45 Total natural gas revenues $ 105 $ — $ 543 $ — $ (1) $ 647 Total revenues (b) $ 1,864 $ 1,164 $ 543 $ 324 $ (73) $ 3,822 (a) Includes over-recoveries of various riders. (b) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and six months ended June 30, 2024 and 2023: Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Ameren Three Months 2024: Revenues from alternative revenue programs $ (1) $ 22 $ — $ 4 $ 25 Other revenues not from contracts with customers 1 1 1 — 3 Three Months 2023: Revenues from alternative revenue programs $ — $ 60 $ 9 $ 5 $ 74 Other revenues not from contracts with customers (2) (a) 2 1 — 1 (a) Six Months 2024: Revenues from alternative revenue programs $ (7) $ 61 $ 19 $ 13 $ 86 Other revenues not from contracts with customers 2 3 2 — 7 Six Months 2023: Revenues from alternative revenue programs $ (2) $ 124 $ 37 $ 13 $ 172 Other revenues not from contracts with customers (8) (a) 4 2 — (2) (a) (a) Includes net realized losses on derivative power contracts. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois Three Months 2024: Residential $ 311 $ 102 $ — $ — $ 413 Commercial 163 24 — — 187 Industrial 47 1 — — 48 Other (12) (a) 21 136 (27) 118 Total revenues (b) $ 509 $ 148 $ 136 $ (27) $ 766 Three Months 2023: Residential $ 337 $ 98 $ — $ — $ 435 Commercial 193 25 — — 218 Industrial 48 2 — — 50 Other (38) (a) 27 113 (26) 76 Total revenues (b) $ 540 $ 152 $ 113 $ (26) $ 779 Six Months 2024: Residential $ 608 $ 389 $ — $ — $ 997 Commercial 328 92 — — 420 Industrial 92 5 — — 97 Other (13) (a) 53 267 (55) 252 Total revenues (b) $ 1,015 $ 539 $ 267 $ (55) $ 1,766 Six Months 2023: Residential $ 719 $ 394 $ — $ — $ 1,113 Commercial 393 102 — — 495 Industrial 96 9 — — 105 Other (44) (a) 38 227 (54) 167 Total revenues (b) $ 1,164 $ 543 $ 227 $ (54) $ 1,880 (a) Includes over-recoveries of various riders. (b) 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 six months ended June 30, 2024 and 2023: Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois Three Months 2024: Revenues from alternative revenue programs $ 22 $ — $ 2 $ 24 Other revenues not from contracts with customers 1 1 — 2 Three Months 2023: Revenues from alternative revenue programs $ 60 $ 9 $ 3 $ 72 Other revenues not from contracts with customers 2 1 — 3 Six Months 2024: Revenues from alternative revenue programs $ 61 $ 19 $ 10 $ 90 Other revenues not from contracts with customers 3 2 — 5 Six Months 2023: Revenues from alternative revenue programs $ 124 $ 37 $ 10 $ 171 Other revenues not from contracts with customers 4 2 — 6 |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Unconsolidated variable interest | $ 75 | $ 73 |
Cash Surrender Value of Life Insurance | 255 | 248 |
Corporate owned life insurance, borrowings | 103 | 104 |
Ameren Illinois Company | ||
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Cash Surrender Value of Life Insurance | 114 | 111 |
Corporate owned life insurance, borrowings | 103 | $ 104 |
Partnership Funding Commitment | ||
Basis Of Presentation And Significant Accounting Policies [Line Items] | ||
Outstanding funding commitments | $ 12 |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative-Missouri) (Details) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | |||||
Nov. 30, 2023 USD ($) | Jun. 30, 2024 MWh | Sep. 30, 2023 MWh | Dec. 31, 2022 MWh | Sep. 30, 2022 MWh | Jun. 30, 2022 MWh | Jun. 30, 2024 USD ($) MWh | Jun. 30, 2023 USD ($) | Dec. 31, 2025 USD ($) | |
Rate And Regulatory Matters [Line Items] | |||||||||
Capital expenditures | $ 1,892 | $ 1,822 | |||||||
Union Electric Company | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Capital expenditures | 1,104 | $ 914 | |||||||
Cass County Solar Project Purchase Price | 250 | ||||||||
Union Electric Company | Rush Island Energy Center | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
MoPSC Approved Costs to be Securitized | $ 470 | ||||||||
Requested Costs to be Securitized | $ 519 | ||||||||
Regulatory Asset, Amortization Period | 15 years | ||||||||
Union Electric Company | Solar generation facility | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Amount of Megawatts | MWh | 500 | ||||||||
Capital expenditures | $ 850 | ||||||||
Union Electric Company | Electric | Pending Rate Case | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 446 | ||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.25% | ||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 52% | ||||||||
Rate Base | $ 14,000 | ||||||||
Months to complete a rate proceeding | 11 months | ||||||||
Union Electric Company | Electric | MEEIA 2024 | Forecast | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Energy efficiency investments in MEEIA 2019 programs | $ 123 | ||||||||
Percentage of MEEIA Energy Efficiency Goals Achieved | 100% | ||||||||
Incentive award if energy efficiency goals are achieved | $ 56 | ||||||||
Incentive award if energy efficiency goals are exceeded | $ 14 | ||||||||
Union Electric Company | Build-transfer | Solar generation facility | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Amount of Megawatts | MWh | 300 | 200 | 150 | ||||||
Union Electric Company | Development-transfer | Solar generation facility | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Amount of Megawatts | MWh | 150 | ||||||||
Union Electric Company | Self-build | Solar generation facility | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Amount of Megawatts | MWh | 50 | 50 | |||||||
Union Electric Company | Self-build | Natural Gas Generation Facility | |||||||||
Rate And Regulatory Matters [Line Items] | |||||||||
Amount of Megawatts | MWh | 800 |
Rate And Regulatory Matters (_2
Rate And Regulatory Matters (Narrative-Illinois) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | ||||||
Dec. 31, 2023 | Nov. 30, 2023 | Oct. 31, 2023 | Sep. 30, 2024 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2027 | Dec. 31, 2026 | Dec. 31, 2025 | Dec. 31, 2024 | |
Rate And Regulatory Matters [Line Items] | ||||||||||
Capital expenditures | $ 1,892 | $ 1,822 | ||||||||
Ameren Illinois Company | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Capital expenditures | 717 | $ 844 | ||||||||
Ameren Illinois Company | Natural gas | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 52% | |||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.89% | |||||||||
IETL | Ameren Illinois Company | Electric Distribution | Forecast | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Approved return on equity percentage | 8.72% | 8.72% | 8.72% | 8.72% | ||||||
Multi-year rate plan rehearing approved revenue requirement | $ 1,397 | $ 1,350 | $ 1,282 | $ 1,196 | ||||||
Approved rate base | 4,700 | 4,500 | 4,300 | 4,000 | ||||||
Revised multi-year rate plan requested revenue requirement | 1,446 | 1,386 | 1,300 | 1,215 | ||||||
Revised multi-year rate plan requested rate base | 5,000 | 4,800 | 4,500 | 4,300 | ||||||
ICC staff revised multi-year rate plan recommended revenue requirement | 1,414 | 1,361 | 1,281 | 1,201 | ||||||
ICC staff revised multi-year rate plan recommended rate base | $ 4,800 | $ 4,600 | $ 4,400 | $ 4,200 | ||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 50% | 50% | 50% | 50% | ||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 285 | |||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 334 | |||||||||
ICC staff recommended rate increase | $ 302 | |||||||||
Pending Rate Case | Ameren Illinois Company | Electric Distribution | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
ICC staff recommended rate increase | 157 | |||||||||
Pending Rate Case | Ameren Illinois Company | Electric Distribution | Subsequent Event | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 158 | |||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 50% | |||||||||
Pending Rate Case | Ameren Illinois Company | Electric Energy-Efficiency | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 26 | |||||||||
Pending Rate Case | Ameren Illinois Company | Natural gas | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Capital expenditures | $ 53 | |||||||||
Over-Recovery Challenged by the Attorney General | $ 3 | |||||||||
Final Rate Order | Ameren Illinois Company | Natural gas | ||||||||||
Rate And Regulatory Matters [Line Items] | ||||||||||
Approved return on equity percentage | 9.44% | |||||||||
Approved rate base | $ 2,850 | |||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 50% | |||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 112 | |||||||||
Capital expenditures | $ 93 | $ 93 |
Rate And Regulatory Matters (_3
Rate And Regulatory Matters (Narrative-Federal) (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||
May 31, 2020 | Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Rate And Regulatory Matters [Line Items] | |||||
ROE Change | 0.50% | ||||
Revenues | $ 1,693 | $ 1,760 | $ 3,509 | $ 3,822 | |
Ameren Illinois Company | |||||
Rate And Regulatory Matters [Line Items] | |||||
Revenues | $ 766 | $ 779 | 1,766 | $ 1,880 | |
Midwest Independent Transmission System Operator, Inc | |||||
Rate And Regulatory Matters [Line Items] | |||||
Revenues | 21 | ||||
Midwest Independent Transmission System Operator, Inc | Ameren Illinois Company | |||||
Rate And Regulatory Matters [Line Items] | |||||
Revenues | $ 15 | ||||
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 | 6 Months Ended | ||
Jun. 30, 2024 USD ($) | Jun. 30, 2023 | Jun. 30, 2024 USD ($) | Jun. 30, 2023 | |
Credit Agreements | ||||
Short-term Debt [Line Items] | ||||
Net Liquidity Available | $ 1.9 | $ 1.9 | ||
Actual debt-to-capital ratio | 0.61 | 0.61 | ||
Utilities | ||||
Short-term Debt [Line Items] | ||||
Short-term Debt, Weighted Average Interest Rate, over Time | 5.51% | 5.28% | 5.41% | 5.04% |
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 | Jun. 30, 2024 | Dec. 31, 2023 |
Short-term Debt [Line Items] | ||
Short-term debt | $ 691 | $ 536 |
Union Electric Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 390 | 170 |
Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 0 | 366 |
Commercial Paper | ||
Short-term Debt [Line Items] | ||
Short-term debt | 691 | 536 |
Commercial Paper | Parent Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 301 | 0 |
Commercial Paper | Union Electric Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | 390 | 170 |
Commercial Paper | Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Short-term debt | $ 0 | $ 366 |
Short-Term Debt and Liquidity_4
Short-Term Debt and Liquidity (Short-Term Debt Activity) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 578 | $ 1,168 |
Weighted-average interest rate | 5.56% | 5.10% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 1,084 | $ 1,381 |
Peak interest rate | 5.68% | 5.60% |
Parent Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 84 | $ 595 |
Weighted-average interest rate | 5.55% | 5.14% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 301 | $ 841 |
Peak interest rate | 5.60% | 5.55% |
Union Electric Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 109 | $ 343 |
Weighted-average interest rate | 5.53% | 5.04% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 509 | $ 592 |
Peak interest rate | 5.68% | 5.55% |
Ameren Illinois Company | ||
Short-term Debt [Line Items] | ||
Average daily amount outstanding | $ 385 | $ 230 |
Weighted-average interest rate | 5.57% | 5.10% |
Short-term Debt, Maximum Amount Outstanding During Period | $ 694 | $ 450 |
Peak interest rate | 5.68% | 5.60% |
Long-Term debt and Equity Fin_2
Long-Term debt and Equity Financings (Details) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2024 USD ($) shares | Mar. 31, 2024 USD ($) shares | Jun. 30, 2023 USD ($) shares | Jun. 30, 2024 USD ($) $ / shares shares | Jun. 30, 2023 USD ($) shares | Apr. 30, 2024 USD ($) | Jan. 31, 2024 USD ($) | |
Long-Term Debt And Equity Financings [Line Items] | |||||||
Shares issued under the DRPlus and 401(k) plan | shares | 0.2 | 0.1 | 0.3 | 0.2 | |||
Issuances of common stock | $ 21 | $ 16 | |||||
Stock Issued During Period, Shares, Other | shares | 0 | 0.2 | 0 | 0.2 | 0.5 | ||
Stock Issued During Period, Value, Other | $ 16 | ||||||
Maximum Value Of Shares To Be Issued Under ATM Program | $ 770 | $ 770 | |||||
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 | $ 76.69 | ||||||
Maximum | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares | 89.31 | ||||||
Weighted Average | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares | $ 80.45 | ||||||
Dividend reinvestment and 401 (k) plans | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Issuances of common stock | $ 4 | $ 14 | |||||
Accrued Proceeds from Issuance of Common Stock | $ 7 | ||||||
Forward Sale Agreements Outstanding | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Forward Contract Indexed to Issuer's Equity, Settlement Alternatives, Shares, at Fair Value | shares | 2.9 | 2.9 | |||||
Forward Contract Indexed to Issuer's Equity, Settlement Alternatives, Cash, at Fair Value | $ 232 | $ 232 | |||||
Period End Net Cash Settlement Price | 29 | 29 | |||||
Period End Net Share Settlement Price | $ 0.4 | $ 0.4 | |||||
Forward Sale Agreement Equity Offering Shares | shares | 2.9 | 2.9 | |||||
Forward Sale Agreement Gross Sales Price | $ 232 | $ 232 | |||||
Union Electric Company | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Capital contributions from parent | 350 | $ 0 | |||||
Union Electric Company | Other Paid-in Capital: | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Capital contributions from parent | 350 | $ 0 | 350 | $ 0 | |||
Union Electric Company | Secured Debt | First Mortgage Bonds, 5.25%, Due 2054 - $350 Issuance | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Debt Instrument, Face Amount | $ 350 | ||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.25% | ||||||
Union Electric Company | Secured Debt | Senior Secured Notes 5.20% Due 2034 | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Debt Instrument, Face Amount | $ 500 | ||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.20% | ||||||
Union Electric Company | Secured Debt | Senior Secured Notes350 Due2024 | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Debt Instrument, Face Amount | $ 350 | ||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | ||||||
Ameren Illinois Company | Secured Debt | First Mortgage Bonds, 5.55%, Due 2054 - $625 Issuance | |||||||
Long-Term Debt And Equity Financings [Line Items] | |||||||
Debt Instrument, Face Amount | $ 625 | $ 625 | |||||
Debt Instrument, Interest Rate, Stated Percentage | 5.55% | 5.55% |
Other Income, Net (Details)
Other Income, Net (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | $ 16 | $ 14 | $ 25 | $ 23 |
Other interest income | 13 | 9 | 21 | 17 |
Non-service cost components of net periodic benefit income | 76 | 63 | 152 | 127 |
Miscellaneous income | 4 | 2 | 6 | 4 |
Income (Loss) from Equity Method Investments | 1 | 0 | 1 | 2 |
Donations | (2) | (2) | (4) | (4) |
Miscellaneous expense | (5) | (4) | (9) | (9) |
Total Other Income, Net | 103 | 82 | 192 | 160 |
Union Electric Company | ||||
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | 14 | 8 | 23 | 12 |
Other interest income | 3 | 2 | 5 | 6 |
Non-service cost components of net periodic benefit income | 35 | 14 | 69 | 28 |
Miscellaneous income | 0 | 1 | 2 | 2 |
Donations | (1) | (1) | (2) | (2) |
Miscellaneous expense | (2) | (2) | (4) | (5) |
Total Other Income, Net | 49 | 22 | 93 | 41 |
Defined Benefit Plan, Non-service Cost or Income Components - Tracker | (11) | 17 | (20) | 34 |
Ameren Illinois Company | ||||
Other Nonoperating Income (Expense) [Line Items] | ||||
Allowance for equity funds used during construction | 2 | 6 | 2 | 10 |
Other interest income | 9 | 6 | 15 | 10 |
Non-service cost components of net periodic benefit income | 26 | 31 | 53 | 62 |
Miscellaneous income | 2 | 1 | 3 | 2 |
Donations | (1) | (1) | (2) | (2) |
Miscellaneous expense | (1) | (2) | (3) | (4) |
Total Other Income, Net | $ 37 | $ 41 | $ 68 | $ 78 |
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 | 6 Months Ended | 12 Months Ended |
Jun. 30, 2024 MWh MMBTU lb gal | Dec. 31, 2023 MWh MMBTU lb gal | |
Fuel oils | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Volume | gal | 20 | 17 |
Natural gas | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU | 273 | 271 |
Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 5 | 5 |
Uranium | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Mass | lb | 0 | 186 |
Union Electric Company | Fuel oils | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Volume | gal | 20 | 17 |
Union Electric Company | Natural gas | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU | 52 | 53 |
Union Electric Company | Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 0 | 0 |
Union Electric Company | Uranium | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Mass | lb | 0 | 186 |
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 | 221 | 218 |
Ameren Illinois Company | Power | ||
Derivative [Line Items] | ||
Derivative, Nonmonetary Notional Amount, Energy Measure | MWh | 5 | 5 |
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 | Jun. 30, 2024 | Dec. 31, 2023 |
Derivative [Line Items] | ||
Derivative Assets | $ 24 | $ 22 |
Derivative Liability | 141 | 168 |
Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 2 | 2 |
Fuel oils | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 1 |
Fuel oils | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 1 |
Natural gas | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 4 | 0 |
Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative Assets | 3 | 6 |
Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 42 | 57 |
Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 36 | 40 |
Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 15 | 5 |
Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 12 | 13 |
Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 50 | 56 |
Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 0 | 9 |
Union Electric Company | ||
Derivative [Line Items] | ||
Derivative Assets | 20 | 19 |
Derivative Liability | 19 | 25 |
Union Electric Company | Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 2 | 2 |
Union Electric Company | Fuel oils | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 1 |
Union Electric Company | Fuel oils | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 1 |
Union Electric Company | Natural gas | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 1 | 0 |
Union Electric Company | Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative Assets | 2 | 3 |
Union Electric Company | Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 9 | 12 |
Union Electric Company | Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 8 | 10 |
Union Electric Company | Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 15 | 5 |
Union Electric Company | Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 1 | 1 |
Union Electric Company | Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 0 | 0 |
Union Electric Company | Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 0 | 9 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Derivative Assets | 4 | 3 |
Derivative Liability | 122 | 143 |
Ameren Illinois Company | Fuel oils | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 0 | 0 |
Ameren Illinois Company | Fuel oils | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 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 | 3 | 0 |
Ameren Illinois Company | Natural gas | Other assets | ||
Derivative [Line Items] | ||
Derivative Assets | 1 | 3 |
Ameren Illinois Company | Natural gas | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 33 | 45 |
Ameren Illinois Company | Natural gas | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 28 | 30 |
Ameren Illinois Company | Power | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | 0 | 0 |
Ameren Illinois Company | Power | Other current liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 11 | 12 |
Ameren Illinois Company | Power | Other deferred credits and liabilities | ||
Derivative [Line Items] | ||
Derivative Liability | 50 | 56 |
Ameren Illinois Company | Uranium | Other current assets | ||
Derivative [Line Items] | ||
Derivative Assets | $ 0 | $ 0 |
Derivative Financial Instrume_5
Derivative Financial Instruments (Offsetting Assets and Liabilities) (Details) - Not Designated As Hedging Instrument - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | $ 24 | $ 22 |
Gross derivative instruments not offset in the balance sheet | 7 | 7 |
Gross cash collateral received not offset in the balance sheet | 0 | 0 |
Net derivative asset | 17 | 15 |
Gross derivative liability amount recognized on the balance sheet | 141 | 168 |
Gross derivative instruments not offset in the balance sheet | 7 | 7 |
Gross cash collateral posted not offset in the balance sheet | 0 | 6 |
Net derivative liability | 134 | 155 |
Union Electric Company | ||
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | 20 | 19 |
Gross derivative instruments not offset in the balance sheet | 5 | 6 |
Gross cash collateral received not offset in the balance sheet | 0 | 0 |
Net derivative asset | 15 | 13 |
Gross derivative liability amount recognized on the balance sheet | 19 | 25 |
Gross derivative instruments not offset in the balance sheet | 5 | 6 |
Gross cash collateral posted not offset in the balance sheet | 0 | 0 |
Net derivative liability | 14 | 19 |
Ameren Illinois Company | ||
Derivative [Line Items] | ||
Gross derivative asset amount recognized on the balance sheet | 4 | 3 |
Gross derivative instruments not offset in the balance sheet | 2 | 1 |
Gross cash collateral received not offset in the balance sheet | 0 | 0 |
Net derivative asset | 2 | 2 |
Gross derivative liability amount recognized on the balance sheet | 122 | 143 |
Gross derivative instruments not offset in the balance sheet | 2 | 1 |
Gross cash collateral posted not offset in the balance sheet | 0 | 6 |
Net derivative liability | $ 120 | $ 136 |
Derivative Financial Instrume_6
Derivative Financial Instruments (Derivative Instruments with Credit Risk-Related Contingent Features) (Details) $ in Millions | Jun. 30, 2024 USD ($) |
Derivative [Line Items] | |
Aggregate Fair Value of Derivative Liabilities | $ 80 |
Cash Collateral Posted | 0 |
Potential Aggregate Amount of Additional Collateral Required | 72 |
Union Electric Company | |
Derivative [Line Items] | |
Aggregate Fair Value of Derivative Liabilities | 19 |
Cash Collateral Posted | 0 |
Potential Aggregate Amount of Additional Collateral Required | 13 |
Ameren Illinois Company | |
Derivative [Line Items] | |
Aggregate Fair Value of Derivative Liabilities | 61 |
Cash Collateral Posted | 0 |
Potential Aggregate Amount of Additional Collateral Required | $ 59 |
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 | Jun. 30, 2024 | Dec. 31, 2023 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | $ 1,256 | $ 1,141 |
Assets fair value | 1,280 | 1,163 |
Excluded receivables, payables, and accrued income, net | 10 | 9 |
Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 842 | 787 |
Assets fair value | 843 | 789 |
Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 414 | 354 |
Assets fair value | 418 | 358 |
Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Assets fair value | 19 | 16 |
Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 24 | 22 |
Derivative Liability | 141 | 168 |
Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 1 | 2 |
Derivative Liability | 3 | 6 |
Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 4 | 4 |
Derivative Liability | 68 | 79 |
Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 19 | 16 |
Derivative Liability | 70 | 83 |
Union Electric Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 1,256 | 1,141 |
Assets fair value | 1,276 | 1,160 |
Union Electric Company | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 842 | 787 |
Assets fair value | 843 | 789 |
Union Electric Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 414 | 354 |
Assets fair value | 417 | 357 |
Union Electric Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 0 | 0 |
Assets fair value | 16 | 14 |
Union Electric Company | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 20 | 19 |
Derivative Liability | 19 | 25 |
Union Electric Company | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 1 | 2 |
Derivative Liability | 1 | 2 |
Union Electric Company | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 3 | 3 |
Derivative Liability | 16 | 19 |
Union Electric Company | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 16 | 14 |
Derivative Liability | 2 | 4 |
Union Electric Company | Fuel oils | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 2 | 2 |
Derivative Liability | 1 | 2 |
Union Electric Company | Fuel oils | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 1 | 2 |
Derivative Liability | 1 | 2 |
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 | 1 | 0 |
Derivative Liability | 0 | 0 |
Union Electric Company | Natural gas | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 3 | 3 |
Derivative Liability | 17 | 22 |
Union Electric Company | Natural gas | 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 | Natural gas | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 3 | 3 |
Derivative Liability | 16 | 19 |
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 | 3 |
Union Electric Company | Power | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 15 | 5 |
Derivative Liability | 1 | 1 |
Union Electric Company | Power | 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 | 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 | 15 | 5 |
Derivative Liability | 1 | 1 |
Union Electric Company | Uranium | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 0 | 9 |
Union Electric Company | Uranium | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 0 | 0 |
Union Electric Company | Uranium | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 0 | 0 |
Union Electric Company | Uranium | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 0 | 9 |
Union Electric Company | Equity securities: | U.S. large capitalization | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Nuclear decommissioning trust fund: | 842 | 787 |
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: | 842 | 787 |
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: | 178 | 150 |
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: | 178 | 150 |
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: | 154 | 136 |
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: | 154 | 136 |
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: | 82 | 68 |
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: | 82 | 68 |
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 | 4 | 3 |
Ameren Illinois Company | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 0 | 0 |
Ameren Illinois Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 1 | 1 |
Ameren Illinois Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Assets fair value | 3 | 2 |
Ameren Illinois Company | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 122 | 143 |
Ameren Illinois Company | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 2 | 4 |
Ameren Illinois Company | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 52 | 60 |
Ameren Illinois Company | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 68 | 79 |
Ameren Illinois Company | Natural gas | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 4 | 3 |
Derivative Liability | 61 | 75 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 0 | 0 |
Derivative Liability | 2 | 4 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 1 | 1 |
Derivative Liability | 52 | 60 |
Ameren Illinois Company | Natural gas | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Assets | 3 | 2 |
Derivative Liability | 7 | 11 |
Ameren Illinois Company | Power | Commodity Contract | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 61 | 68 |
Ameren Illinois Company | Power | Commodity Contract | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Power | Commodity Contract | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | 0 | 0 |
Ameren Illinois Company | Power | Commodity Contract | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Derivative Liability | $ 61 | $ 68 |
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 | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | $ (52) | $ (47) | $ (64) | $ (21) |
Included in regulatory assets/liabilities | 3 | (6) | 12 | (33) |
Settlements, assets | 2 | 0 | ||
Settlement, liabilities | (1) | 5 | ||
Change in unrealized gains (losses) related to assets/liabilities held at period end | 2 | (6) | 14 | (21) |
Ending balance | (47) | (54) | (47) | (54) |
Union Electric Company | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | 2 | 5 | 4 | 12 |
Included in regulatory assets/liabilities | 15 | 14 | 14 | 8 |
Settlements, assets | 6 | |||
Settlement, liabilities | (3) | (5) | (4) | |
Change in unrealized gains (losses) related to assets/liabilities held at period end | 14 | 14 | 14 | 14 |
Ending balance | 14 | 14 | 14 | 14 |
Ameren Illinois Company | ||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | ||||
Beginning balance | (54) | (52) | (68) | (33) |
Included in regulatory assets/liabilities | (12) | (20) | (2) | (41) |
Settlements, assets | 5 | 4 | 9 | |
Settlement, liabilities | 6 | |||
Change in unrealized gains (losses) related to assets/liabilities held at period end | (12) | (20) | 0 | (35) |
Ending balance | $ (61) | $ (68) | $ (61) | $ (68) |
Fair Value Measurements (Sche_3
Fair Value Measurements (Schedule Of Valuation Process And Unobservable Inputs) (Details) - Power $ in Millions | Jun. 30, 2024 USD ($) $ / MWh | Dec. 31, 2023 USD ($) $ / MWh |
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Derivative Assets | $ | $ 15 | $ 5 |
Derivative liabilities | $ | $ (62) | $ (69) |
Commodity Forward Price | Discounted cash flow | Minimum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 33 | 31 |
Commodity Forward Price | Discounted cash flow | Maximum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 70 | 65 |
Commodity Forward Price | Discounted cash flow | Weighted Average | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | 43 | 43 |
Nodal Basis | Discounted cash flow | Minimum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | (10) | (8) |
Nodal Basis | Discounted cash flow | Maximum | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | (1) | (1) |
Nodal Basis | Discounted cash flow | Weighted Average | ||
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items] | ||
Measurement input | (5) | (5) |
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 | Jun. 30, 2024 | Dec. 31, 2023 |
Carrying Amount(a) | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-Term Debt, Carrying Amount | $ 17,079 | $ 15,970 |
Debt Issuance Costs, Net | 124 | 111 |
Carrying Amount(a) | Union Electric Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-Term Debt, Carrying Amount | 6,830 | 6,341 |
Debt Issuance Costs, Net | 53 | 45 |
Carrying Amount(a) | Ameren Illinois Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-Term Debt, Carrying Amount | 5,851 | 5,232 |
Debt Issuance Costs, Net | 52 | 47 |
Fair Value | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 15,450 | 14,833 |
Fair Value | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 14,990 | 14,366 |
Fair Value | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 460 | 467 |
Fair Value | Union Electric Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 6,069 | 5,800 |
Fair Value | Union Electric Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 6,069 | 5,800 |
Fair Value | Union Electric Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 0 | 0 |
Fair Value | Ameren Illinois Company | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 5,251 | 4,867 |
Fair Value | Ameren Illinois Company | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | 5,251 | 4,867 |
Fair Value | Ameren Illinois Company | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term Debt, Fair Value | $ 0 | $ 0 |
Related Party Transactions (Nar
Related Party Transactions (Narrative) (Details) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Related Party Transaction [Line Items] | ||
Other assets | $ 1,049 | $ 921 |
Union Electric Company | ||
Related Party Transaction [Line Items] | ||
Other assets | 194 | 152 |
Ameren Illinois Company | ||
Related Party Transaction [Line Items] | ||
Other assets | 656 | 603 |
Ameren Services Support Services Agreement | Union Electric Company | Related Party | ||
Related Party Transaction [Line Items] | ||
Other assets | 22 | 31 |
Ameren Services Support Services Agreement | Ameren Illinois Company | Related Party | ||
Related Party Transaction [Line Items] | ||
Other assets | $ 24 | $ 34 |
Related Party Transactions (Sch
Related Party Transactions (Schedule of Affiliate Receivables and Payables) (Details) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | $ 774 | $ 1,136 |
Accounts Receivable, Related Parties, Current | 514 | 494 |
Union Electric Company | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 58 | 53 |
Accounts Receivable, Related Parties, Current | 67 | 72 |
Union Electric Company | Income taxes payable to parent | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 0 | 0 |
Union Electric Company | Income taxes receivable from parent | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | 54 | 56 |
Ameren Illinois Company | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 97 | 52 |
Accounts Receivable, Related Parties, Current | 11 | 35 |
Ameren Illinois Company | Income taxes payable to parent | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 44 | 2 |
Ameren Illinois Company | Income taxes receivable from parent | Related Party | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | $ 0 | $ 22 |
Related Party Transactions (Eff
Related Party Transactions (Effects of Related-party Transactions on the Statement of Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Related Party Transaction [Line Items] | ||||
Operating Revenues | $ 1,693 | $ 1,760 | $ 3,509 | $ 3,822 |
Other operations and maintenance | 465 | 450 | 935 | 898 |
(Interest Charges)/Other Income, Net | (165) | (134) | (319) | (261) |
Union Electric Company | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 888 | 941 | 1,663 | 1,864 |
Other operations and maintenance | 247 | 237 | 501 | 476 |
(Interest Charges)/Other Income, Net | (63) | (52) | (125) | (103) |
Union Electric Company | Ameren Missouri Power Supply Agreements with Ameren Illinois | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Union Electric Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 8 | 8 | 15 | 18 |
Other operations and maintenance | 1 | 1 | 1 | 1 |
Union Electric Company | Ameren Missouri and Ameren Illinois Miscellaneous Support Services | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Union Electric Company | Total Related Party Operating Revenues | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 9 | 8 | 16 | 18 |
Union Electric Company | Ameren Missouri and Ameren Illinois Transmission Services from ATXI | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Purchased Power | 2 | 1 | 4 | 1 |
Union Electric Company | Purchased Power | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Purchased Power | 2 | 1 | 4 | 1 |
Union Electric Company | Ameren Services Support Services Agreement | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Other operations and maintenance | 43 | 35 | 81 | 70 |
Union Electric Company | Total Related Party Other Operations and Maintenance | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Other operations and maintenance | 43 | 35 | 81 | 70 |
Union Electric Company | Money pool interest | Related Party | ||||
Related Party Transaction [Line Items] | ||||
(Interest Charges)/Other Income, Net | (1) | (1) | (3) | (1) |
Ameren Illinois Company | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 766 | 779 | 1,766 | 1,880 |
Purchased Power | 141 | 192 | 305 | 479 |
Other operations and maintenance | 224 | 201 | 434 | 403 |
(Interest Charges)/Other Income, Net | (60) | (50) | (115) | (97) |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Rent and Facility Services | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Other operations and maintenance | 1 | 1 | 1 | 2 |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Miscellaneous Support Services | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Total Related Party Operating Revenues | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Ameren Illinois Power Supply Agreements with Ameren Missouri | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Purchased Power | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Ameren Missouri and Ameren Illinois Transmission Services from ATXI | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Purchased Power | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Purchased Power | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Purchased Power | 1 | 1 | 1 | 1 |
Ameren Illinois Company | Ameren Services Support Services Agreement | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Other operations and maintenance | 40 | 33 | 77 | 68 |
Ameren Illinois Company | Total Related Party Other Operations and Maintenance | Related Party | ||||
Related Party Transaction [Line Items] | ||||
Other operations and maintenance | 40 | 33 | 77 | 70 |
Ameren Illinois Company | Money pool interest | Related Party | ||||
Related Party Transaction [Line Items] | ||||
(Interest Charges)/Other Income, Net | $ (1) | $ (1) | $ (2) | $ (1) |
Commitments And Contingencies (
Commitments And Contingencies (Environmental Matters) (Detail) $ in Millions | Jun. 30, 2024 USD ($) scrubber site | May 30, 2024 USD ($) | Dec. 31, 2023 USD ($) |
Loss Contingencies [Line Items] | |||
Asset Retirement Obligation | $ 810 | $ 791 | |
Minimum | |||
Loss Contingencies [Line Items] | |||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 90 | ||
Maximum | |||
Loss Contingencies [Line Items] | |||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | $ 120 | ||
Union Electric Company | |||
Loss Contingencies [Line Items] | |||
Number of Energy Center Scrubbers | scrubber | 2 | ||
Asset Retirement Obligation | $ 807 | 787 | |
Union Electric Company | Coal Fired Electric Generation Equipment | |||
Loss Contingencies [Line Items] | |||
Plant To Be Abandoned, Net | 508 | ||
Union Electric Company | Minimum | |||
Loss Contingencies [Line Items] | |||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 90 | ||
Union Electric Company | Maximum | |||
Loss Contingencies [Line Items] | |||
Estimated capital costs to comply with existing and known federal and state air emissions regulations | 120 | ||
Ameren Illinois Company | |||
Loss Contingencies [Line Items] | |||
Asset Retirement Obligation | 3 | $ 4 | |
Rush Island Energy Center Additional Mitigation Relief Proposed by Ameren Missouri | Union Electric Company | |||
Loss Contingencies [Line Items] | |||
Estimate of possible loss | 20 | ||
Accrual for environmental loss contingencies | 20 | ||
Rush Island Energy Center Additional Mitigation Relief Proposed by Department of Justice | Union Electric Company | |||
Loss Contingencies [Line Items] | |||
Estimate of possible loss | $ 120 | ||
Manufactured Gas Plant | |||
Loss Contingencies [Line Items] | |||
Accrual for environmental loss contingencies | 45 | ||
Manufactured Gas Plant | Ameren Illinois Company | |||
Loss Contingencies [Line Items] | |||
Accrual for environmental loss contingencies | $ 45 | ||
Number of remediation sites | site | 44 | ||
Manufactured Gas Plant | Ameren Illinois Company | Minimum | |||
Loss Contingencies [Line Items] | |||
Estimate of possible loss | $ 45 | ||
Manufactured Gas Plant | Ameren Illinois Company | Maximum | |||
Loss Contingencies [Line Items] | |||
Estimate of possible loss | 95 | ||
New CCR Rules Estimate | |||
Loss Contingencies [Line Items] | |||
Asset Retirement Obligation | 42 | ||
New CCR Rules Estimate | Union Electric Company | |||
Loss Contingencies [Line Items] | |||
Asset Retirement Obligation | $ 42 |
Callaway Energy Center (Insuran
Callaway Energy Center (Insurance Disclosure) (Details) $ in Millions | 6 Months Ended |
Jun. 30, 2024 USD ($) yr | |
Nuclear Waste Matters [Line Items] | |
Decommissioning Cost | $ 7 |
Frequency of Decommissioning Cost Study | 3 years |
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 | $ 500 |
Insurance Maximum Coverage per Incident | 0 |
Public Liability And Nuclear Worker Liability - Pool Participation | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 15,763 |
Insurance Maximum Coverage per Incident | 166 |
Threshold Amount For Retrospective Insurance Assessment For Covered Loss Under Public Liability And Nuclear Worker Liability Insurance Policy | 500 |
Maximum Annual Payment Per Incident At Licensed Commercial Nuclear Reactor | 24.7 |
Public Liability | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 16,263 |
Insurance Maximum Coverage per Incident | 166 |
Property Damage - Nuclear Electric Insurance Ltd | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 3,200 |
Insurance Maximum Coverage per Incident | 28 |
Accidental Outage - Nuclear Electric Insurance Ltd | |
Nuclear Waste Matters [Line Items] | |
Insurance Aggregate Maximum Coverage | 490 |
Insurance Maximum Coverage per Incident | 11 |
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 | 291 |
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 | 700 |
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 | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Total non-service cost components | $ (76) | $ (63) | $ (152) | $ (127) |
Pension Plan | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Service Cost | 23 | 23 | 44 | 46 |
Interest cost | 56 | 56 | 111 | 111 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (82) | (84) | (164) | (167) |
Prior service benefit | 0 | 0 | 0 | 0 |
Actuarial (gain) | (16) | (28) | (33) | (57) |
Total non-service cost components | (42) | (56) | (86) | (113) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (19) | (33) | $ (42) | (67) |
Defined Benefit Plan, Amortization Period of Actuarial Gain (Loss) | 10 years | |||
Defined Benefit Plan, Difference Between Actual and Expected Return (Loss) on Plan Assets Amortization Period | 4 years | |||
Other Postretirement Benefit Plan, Defined Benefit | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Service Cost | 3 | 3 | $ 6 | 6 |
Interest cost | 11 | 12 | 22 | 23 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (23) | (23) | (46) | (46) |
Prior service benefit | (1) | (1) | (2) | (2) |
Actuarial (gain) | (10) | (12) | (20) | (23) |
Total non-service cost components | (23) | (24) | (46) | (48) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | $ (20) | $ (21) | $ (40) | $ (42) |
Defined Benefit Plan, Amortization Period of Actuarial Gain (Loss) | 10 years | |||
Defined Benefit Plan, Difference Between Actual and Expected Return (Loss) on Plan Assets Amortization Period | 4 years |
Retirement Benefits (Summary of
Retirement Benefits (Summary of Benefit Plan Costs Incurred) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Pension Plan | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | $ (19) | $ (33) | $ (42) | $ (67) |
Pension Plan | Union Electric Company | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | (10) | (17) | (22) | (35) |
Pension Plan | Ameren Illinois Company | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | (8) | (13) | (17) | (27) |
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) | (3) | (3) | (5) |
Other Postretirement Benefit Plan, Defined Benefit | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Net periodic benefit cost | (20) | (21) | (40) | (42) |
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 | (7) | (7) | (14) | (15) |
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 | (13) | (14) | (26) | (27) |
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 | $ 0 | $ 0 | $ 0 |
Income Taxes (Schedule of Effec
Income Taxes (Schedule of Effective Income Tax Rate Reconciliation) (Details) | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Income Taxes [Line Items] | ||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% |
Increases (decreases) from: | ||||
Amortization of excess deferred taxes | (8.00%) | (7.00%) | (8.00%) | (8.00%) |
Renewable and other tax credits | (4.00%) | (5.00%) | (4.00%) | (4.00%) |
State tax | 5% | 5% | 5% | 5% |
Depreciation differences | (1.00%) | 0% | 0% | 0% |
Other permanent items | 0% | (1.00%) | ||
Effective income tax rate | 13% | 14% | 14% | 13% |
Union Electric Company | ||||
Income Taxes [Line Items] | ||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% |
Increases (decreases) from: | ||||
Amortization of excess deferred taxes | (14.00%) | (15.00%) | (14.00%) | (15.00%) |
Renewable and other tax credits | (8.00%) | (10.00%) | (8.00%) | (10.00%) |
State tax | 3% | 3% | 3% | 3% |
Depreciation differences | (1.00%) | 0% | 0% | 0% |
Other permanent items | 0% | 0% | ||
Effective income tax rate | 1% | (1.00%) | 2% | (1.00%) |
Ameren Illinois Company | ||||
Income Taxes [Line Items] | ||||
Federal statutory corporate income tax rate | 21% | 21% | 21% | 21% |
Increases (decreases) from: | ||||
Amortization of excess deferred taxes | (4.00%) | (2.00%) | (4.00%) | (2.00%) |
Renewable and other tax credits | 0% | 0% | 0% | 0% |
State tax | 7% | 7% | 7% | 7% |
Depreciation differences | 0% | (1.00%) | 0% | (1.00%) |
Other permanent items | 0% | 0% | ||
Effective income tax rate | 24% | 25% | 24% | 25% |
Supplemental Information (Cash
Supplemental Information (Cash and Cash Equivalents) (Details) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 | Jun. 30, 2023 | Dec. 31, 2022 |
Schedule of Cash and Cash Equivalents Including Restricted Cash [Line Items] | ||||
Cash and cash equivalents | $ 19 | $ 25 | ||
Restricted cash included in “Other current assets” | 18 | 13 | ||
Restricted cash included in “Other assets” | 260 | 229 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 4 | 5 | ||
Total cash, cash equivalents, and restricted cash | 301 | 272 | $ 246 | $ 216 |
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” | 7 | 5 | ||
Restricted cash included in “Other assets” | 0 | 0 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 4 | 5 | ||
Total cash, cash equivalents, and restricted cash | 11 | 10 | 8 | 13 |
Ameren Illinois Company | ||||
Schedule of Cash and Cash Equivalents Including Restricted Cash [Line Items] | ||||
Cash and cash equivalents | 6 | 0 | ||
Restricted cash included in “Other current assets” | 7 | 5 | ||
Restricted cash included in “Other assets” | 260 | 229 | ||
Restricted cash included in “Nuclear decommissioning trust fund” | 0 | 0 | ||
Total cash, cash equivalents, and restricted cash | $ 273 | $ 234 | $ 229 | $ 191 |
Supplemental Information (Allow
Supplemental Information (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | $ 37 | $ 34 | $ 30 | $ 31 | |
Bad debt expense | 6 | 13 | 16 | 23 | |
Charged to other accounts | 1 | 1 | 4 | 1 | |
Net write-offs | (7) | (9) | (13) | (16) | |
End of period | 37 | 39 | 37 | 39 | |
Payables for purchased receivables | 49 | 49 | $ 42 | ||
Union Electric Company | |||||
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | 11 | 12 | 12 | 13 | |
Bad debt expense | 4 | 2 | 5 | 4 | |
Net write-offs | (3) | (2) | (5) | (5) | |
End of period | 12 | 12 | 12 | 12 | |
Ameren Illinois Company | |||||
Allowance for Doubtful Accounts Receivable [Roll Forward] | |||||
Beginning of period | 26 | 22 | 18 | 18 | |
Bad debt expense | 2 | 11 | 11 | 19 | |
Charged to other accounts | 1 | 1 | 4 | 1 | |
Net write-offs | (4) | (7) | (8) | (11) | |
End of period | 25 | $ 27 | 25 | $ 27 | |
Payables for purchased receivables | $ 49 | $ 49 | $ 42 |
Supplemental Information (Suppl
Supplemental Information (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Supplemental Cash Flow Information [Line Items] | ||
Accrued capital expenditures, including nuclear fuel expenditures | $ 380 | $ 325 |
Net realized and unrealized gain – nuclear decommissioning trust fund | 103 | 105 |
Return on investment in industrial development revenue bonds | 0 | 240 |
Termination of a financing obligation | 0 | 240 |
Issuance of common stock for stock-based compensation | ||
Supplemental Cash Flow Information [Line Items] | ||
Stock Issued | 16 | 37 |
Issuance of common stock under the DRPlus | ||
Supplemental Cash Flow Information [Line Items] | ||
Stock Issued | 7 | 7 |
Union Electric Company | ||
Supplemental Cash Flow Information [Line Items] | ||
Accrued capital expenditures, including nuclear fuel expenditures | 232 | 132 |
Net realized and unrealized gain – nuclear decommissioning trust fund | 103 | 105 |
Return on investment in industrial development revenue bonds | 0 | 240 |
Termination of a financing obligation | 0 | 240 |
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, including nuclear fuel expenditures | 134 | 173 |
Net realized and unrealized gain – nuclear decommissioning trust fund | 0 | 0 |
Return on investment in industrial development revenue bonds | 0 | 0 |
Termination of a financing obligation | 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 | 6 Months Ended | |
Jun. 30, 2024 | Dec. 31, 2023 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | $ 791 | |
Liabilities incurred | 7 | |
Liabilities settled | (5) | |
Accretion | 17 | |
Asset Retirement Obligation, Ending Balance | 810 | |
Other current liabilities | 655 | $ 501 |
Union Electric Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | 787 | |
Liabilities incurred | 7 | |
Liabilities settled | (4) | |
Accretion | 17 | |
Asset Retirement Obligation, Ending Balance | 807 | |
Other current liabilities | 234 | 153 |
Ameren Illinois Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Asset Retirement Obligation, Beginning Balance | 4 | |
Liabilities incurred | 0 | |
Liabilities settled | (1) | |
Accretion | 0 | |
Asset Retirement Obligation, Ending Balance | 3 | |
Other current liabilities | 219 | 263 |
Asset Retirement Obligation Balance | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Other current liabilities | 19 | 19 |
Asset Retirement Obligation Balance | Union Electric Company | ||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Other current liabilities | $ 19 | $ 19 |
Supplemental Information (Narra
Supplemental Information (Narrative) (Details) - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Effective Income Tax Rate Reconciliation, Share-based Compensation, Excess Tax Benefit, Amount | $ 1 | $ (6) | |
Deferred Compensation Liability, Classified, Noncurrent | $ 80 | $ 85 | |
Q1 2024 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 2024 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 359,133 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Granted in Period, Fair Value | $ 21 | ||
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 2024 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 307,816 | ||
Performance Shares | Renewable generation and energy storage installation targets | Q1 2024 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 51,317 | ||
Restricted Stock Units (RSUs) | Q1 2024 Issuance | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Shares granted (in shares) | 153,887 | ||
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 | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 69 | $ 65 | $ 141 | $ 136 |
Union Electric Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | 41 | 39 | 76 | 73 |
Ameren Illinois Company | ||||
Accounting Policies [Line Items] | ||||
Excise tax expense | $ 28 | $ 26 | $ 65 | $ 63 |
Supplemental Information (Earni
Supplemental Information (Earnings Per Share) (Details) - shares | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Earnings Per Share Reconciliation [Abstract] | ||||
Weighted-average Common Shares Outstanding – Basic | 266,700,000 | 262,600,000 | 266,500,000 | 262,400,000 |
Assumed settlement of performance share units and restricted stock units | 100,000 | 600,000 | 300,000 | 800,000 |
Weighted-average Common Shares Outstanding – Diluted | 266,800,000 | 263,200,000 | 266,800,000 | 263,200,000 |
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 | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Segment Reporting Information [Line Items] | ||||
Operating Revenues | $ 1,693 | $ 1,760 | $ 3,509 | $ 3,822 |
Net income (loss) attributable to common shareholders | 258 | 237 | 519 | 501 |
Capital expenditures | 1,002 | 891 | 1,892 | 1,822 |
Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 888 | 941 | 1,663 | 1,864 |
Net Income (Loss) | 128 | 102 | 153 | 130 |
Ameren Illinois Company | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 766 | 779 | 1,766 | 1,880 |
Net Income (Loss) | 124 | 129 | 339 | 327 |
Capital expenditures | 344 | 437 | 717 | 844 |
Operating Segments | Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 879 | 933 | 1,647 | 1,846 |
Net Income (Loss) | 128 | 102 | 153 | 130 |
Capital expenditures | 638 | 433 | 1,104 | 914 |
Operating Segments | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 509 | 540 | 1,015 | 1,164 |
Net Income (Loss) | 61 | 66 | 117 | 127 |
Capital expenditures | 132 | 180 | 316 | 350 |
Operating Segments | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 148 | 152 | 539 | 543 |
Net Income (Loss) | 6 | 11 | 112 | 98 |
Capital expenditures | 59 | 90 | 119 | 141 |
Operating Segments | Ameren Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 157 | 135 | 308 | 269 |
Net Income (Loss) | 79 | 72 | 151 | 143 |
Capital expenditures | 175 | 197 | 341 | 410 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 509 | 540 | 1,015 | 1,164 |
Net Income (Loss) | 61 | 66 | 117 | 127 |
Capital expenditures | 132 | 180 | 316 | 350 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 148 | 152 | 539 | 543 |
Net Income (Loss) | 6 | 11 | 112 | 98 |
Capital expenditures | 59 | 90 | 119 | 141 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Segment Reporting Information [Line Items] | ||||
Operating Revenues | 109 | 87 | 212 | 173 |
Net Income (Loss) | 57 | 52 | 110 | 102 |
Capital expenditures | 153 | 167 | 282 | 353 |
Other | ||||
Segment Reporting Information [Line Items] | ||||
Net Income (Loss) | (16) | (14) | (14) | 3 |
Capital expenditures | 2 | 2 | 4 | 5 |
Intersegment Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (43) | (34) | (84) | (73) |
Capital expenditures | (4) | (11) | 8 | 2 |
Intersegment Eliminations | Union Electric Company | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (9) | (8) | (16) | (18) |
Intersegment Eliminations | Ameren Illinois Electric Distribution | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | 0 | 0 | 0 | 0 |
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 | (34) | (26) | (68) | (55) |
Intersegment Eliminations | Ameren Illinois Company | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment revenues | (27) | (26) | (55) | (54) |
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 | $ (27) | $ (26) | $ (55) | $ (54) |
Segment Information (Disaggrega
Segment Information (Disaggregation of Revenue) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | $ 1,693 | $ 1,760 | $ 3,509 | $ 3,822 |
Revenues | 1,693 | 1,760 | 3,509 | 3,822 |
Revenues from alternative revenue programs | 25 | 74 | 86 | 172 |
Other revenues not from contracts with customers | 3 | 1 | 7 | (2) |
Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | (1) | 0 | (7) | (2) |
Other revenues not from contracts with customers | 1 | (2) | 2 | (8) |
Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 22 | 60 | 61 | 124 |
Other revenues not from contracts with customers | 1 | 2 | 3 | 4 |
Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 0 | 9 | 19 | 37 |
Other revenues not from contracts with customers | 1 | 1 | 2 | 2 |
Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 4 | 5 | 13 | 13 |
Other revenues not from contracts with customers | 0 | 0 | 0 | 0 |
Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 1,521 | 1,585 | 2,885 | 3,175 |
Revenues | 1,521 | 1,585 | 2,885 | 3,175 |
Electric | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 706 | 697 | 1,344 | 1,403 |
Electric | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 487 | 504 | 911 | 951 |
Electric | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 124 | 123 | 230 | 232 |
Electric | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 204 | 261 | 400 | 589 |
Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 172 | 175 | 624 | 647 |
Revenues | 172 | 175 | 624 | 647 |
Natural gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 115 | 111 | 442 | 459 |
Natural gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 29 | 31 | 113 | 131 |
Natural gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 2 | 3 | 8 | 12 |
Natural gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 26 | 30 | 61 | 45 |
Ameren Illinois Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 766 | 779 | 1,766 | 1,880 |
Revenues | 766 | 779 | 1,766 | 1,880 |
Revenues from alternative revenue programs | 24 | 72 | 90 | 171 |
Other revenues not from contracts with customers | 2 | 3 | 5 | 6 |
Ameren Illinois Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 413 | 435 | 997 | 1,113 |
Ameren Illinois Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 187 | 218 | 420 | 495 |
Ameren Illinois Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 48 | 50 | 97 | 105 |
Ameren Illinois Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 118 | 76 | 252 | 167 |
Ameren Illinois Company | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 22 | 60 | 61 | 124 |
Other revenues not from contracts with customers | 1 | 2 | 3 | 4 |
Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 0 | 9 | 19 | 37 |
Other revenues not from contracts with customers | 1 | 1 | 2 | 2 |
Ameren Illinois Company | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues from alternative revenue programs | 2 | 3 | 10 | 10 |
Other revenues not from contracts with customers | 0 | 0 | 0 | 0 |
Ameren Illinois Company | Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 618 | 627 | 1,227 | 1,337 |
Ameren Illinois Company | Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 148 | 152 | 539 | 543 |
Operating Segments | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 879 | 933 | 1,647 | 1,846 |
Revenues | 888 | 941 | 1,663 | 1,864 |
Operating Segments | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 509 | 540 | 1,015 | 1,164 |
Revenues | 509 | 540 | 1,015 | 1,164 |
Operating Segments | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 148 | 152 | 539 | 543 |
Revenues | 148 | 152 | 539 | 543 |
Operating Segments | Ameren Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 157 | 135 | 308 | 269 |
Revenues | 191 | 161 | 376 | 324 |
Operating Segments | Electric | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 864 | 918 | 1,578 | 1,759 |
Operating Segments | Electric | Union Electric Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 395 | 360 | 736 | 684 |
Operating Segments | Electric | Union Electric Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 324 | 311 | 583 | 558 |
Operating Segments | Electric | Union Electric Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 77 | 75 | 138 | 136 |
Operating Segments | Electric | Union Electric Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 68 | 172 | 121 | 381 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 509 | 540 | 1,015 | 1,164 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 311 | 337 | 608 | 719 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 163 | 193 | 328 | 393 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 47 | 48 | 92 | 96 |
Operating Segments | Electric | Ameren Illinois Electric Distribution | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (12) | (38) | (13) | (44) |
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] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating 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 | 191 | 161 | 376 | 324 |
Operating Segments | Electric | Ameren Transmission | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Electric | Ameren Transmission | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 191 | 161 | 376 | 324 |
Operating Segments | Natural gas | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 24 | 23 | 85 | 105 |
Operating Segments | Natural gas | Union Electric Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 13 | 13 | 53 | 65 |
Operating Segments | Natural gas | Union Electric Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 5 | 6 | 21 | 29 |
Operating Segments | Natural gas | Union Electric Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 1 | 1 | 3 | 3 |
Operating Segments | Natural gas | Union Electric Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 5 | 3 | 8 | 8 |
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] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating 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 | 148 | 152 | 539 | 543 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 102 | 98 | 389 | 394 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 24 | 25 | 92 | 102 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 1 | 2 | 5 | 9 |
Operating Segments | Natural gas | Ameren Illinois Natural Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 21 | 27 | 53 | 38 |
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] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Natural gas | Ameren Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating 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] | ||||
Operating Revenues | 509 | 540 | 1,015 | 1,164 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 148 | 152 | 539 | 543 |
Operating Segments | Ameren Illinois Company | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 109 | 87 | 212 | 173 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 509 | 540 | 1,015 | 1,164 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 311 | 337 | 608 | 719 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 163 | 193 | 328 | 393 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 47 | 48 | 92 | 96 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Electric Distribution | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (12) | (38) | (13) | (44) |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 136 | 113 | 267 | 227 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Operating Segments | Ameren Illinois Company | Electric | Ameren Illinois Transmission | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 136 | 113 | 267 | 227 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 148 | 152 | 539 | 543 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 102 | 98 | 389 | 394 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 24 | 25 | 92 | 102 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 1 | 2 | 5 | 9 |
Operating Segments | Ameren Illinois Company | Natural gas | Ameren Illinois Natural Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 21 | 27 | 53 | 38 |
Intersegment Eliminations | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (43) | (34) | (84) | (73) |
Revenues | (43) | (34) | (84) | (73) |
Intersegment Eliminations | Union Electric Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (9) | (8) | (16) | (18) |
Intersegment Eliminations | Ameren Illinois Electric Distribution | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
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 | (34) | (26) | (68) | (55) |
Intersegment Eliminations | Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (43) | (34) | (84) | (72) |
Intersegment Eliminations | Electric | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Electric | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (43) | (34) | (84) | (72) |
Intersegment Eliminations | Natural gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | (1) |
Intersegment Eliminations | Natural gas | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Natural gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 0 | 0 | 0 | (1) |
Intersegment Eliminations | Ameren Illinois Company | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (27) | (26) | (55) | (54) |
Revenues | (27) | (26) | (55) | (54) |
Intersegment Eliminations | Ameren Illinois Company | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Operating Revenues | 0 | 0 | 0 | 0 |
Intersegment Eliminations | Ameren Illinois Company | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | (27) | (26) | (55) | (54) |
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 | $ (27) | $ (26) | $ (55) | $ (54) |