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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q

☒ | Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the Quarterly Period Ended September 30, 2024

OR

☐ | Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the transition period from to

Commission File Number | Exact name of registrant as specified in its charter; State of Incorporation; Address and Telephone Number | IRS Employer Identification No.
1-14756 | Ameren Corporation | 43-1723446

(Missouri Corporation)
1901 Chouteau Avenue
St. Louis, Missouri 63103
(314) 621-3222

1-2967 | Union Electric Company | 43-0559760

(Missouri Corporation)
1901 Chouteau Avenue
St. Louis, Missouri 63103
(314) 621-3222

1-3672 | Ameren Illinois Company | 37-0211380

(Illinois Corporation)
10 Richard Mark Way
Collinsville, Illinois 62234
(618) 343-8150
Securities Registered Pursuant to Section 12(b) of the Act:

Title of each class | Trading Symbol(s) | Name of each exchange on which registered
Common Stock, $0.01 par value per share | AEE | New York Stock Exchange

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Indicate by check mark whether each registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Ameren Corporation |  | Yes |  | ☒ |  | No |  | ☐
Union Electric Company |  | Yes |  | ☒ |  | No |  | ☐
Ameren Illinois Company |  | Yes |  | ☒ |  | No |  | ☐

Indicate by check mark whether each registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Ameren Corporation |  | Yes |  | ☒ |  | No |  | ☐
Union Electric Company |  | Yes |  | ☒ |  | No |  | ☐
Ameren Illinois Company |  | Yes |  | ☒ |  | No |  | ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Ameren Corporation | Large accelerated filer | ☒ | Accelerated filer | ☐ | Non-accelerated filer | ☐
|  |  | Smaller reporting company | ☐ | Emerging growth company | ☐
Union Electric Company | Large accelerated filer | ☐ | Accelerated filer | ☐ | Non-accelerated filer | ☒
|  |  | Smaller reporting company | ☐ | Emerging growth company | ☐
Ameren Illinois Company | Large accelerated filer | ☐ | Accelerated filer | ☐ | Non-accelerated filer | ☒
|  |  | Smaller reporting company | ☐ | Emerging growth company | ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

Ameren Corporation | ☐
Union Electric Company | ☐
Ameren Illinois Company | ☐

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Ameren Corporation |  | Yes |  | ☐ |  | No |  | ☒
Union Electric Company |  | Yes |  | ☐ |  | No |  | ☒
Ameren Illinois Company |  | Yes |  | ☐ |  | No |  | ☒

The number of shares outstanding of each registrant’s classes of common stock as of October 31, 2024, was as follows:

Registrant |  | Title of each class of common stock | Shares outstanding
Ameren Corporation |  | Common stock, $0.01 par value per share | 266,927,767 |
Union Electric Company |  | Common stock, $5 par value per share, held by Ameren Corporation | 102,123,834 |
Ameren Illinois Company |  | Common stock, no par value, held by Ameren Corporation | 25,452,373 |

This combined Form 10-Q is separately filed by Ameren Corporation, Union Electric Company, and Ameren Illinois Company. Each registrant hereto is filing on its own behalf all of the information contained in this quarterly report that relates to such registrant. Each registrant hereto is not filing any information that does not relate to such registrant, and therefore makes no representation as to any such information.

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TABLE OF CONTENTS

|  | Page
Glossary of Terms and Abbreviations | 1
Forward-looking Statements | 1
PART I. Financial Information |
Item 1. | Financial Statements (Unaudited) | 4
| Ameren Corporation | 4
| Consolidated Statement of Income and Comprehensive Income | 4
| Consolidated Balance Sheet | 5
| Consolidated Statement of Cash Flows | 6
| Consolidated Statement of Shareholders’ Equity | 7
| Union Electric Company (d/b/a Ameren Missouri) | 8
| Consolidated Statement of Income | 8
| Consolidated Balance Sheet | 9
| Consolidated Statement of Cash Flows | 10
| Consolidated Statement of Shareholders’ Equity | 11
| Ameren Illinois Company (d/b/a Ameren Illinois) | 12
| Statement of Income | 12
| Balance Sheet | 13
| Statement of Cash Flows | 14
| Statement of Shareholders’ Equity | 15
| Note 1. Summary of Significant Accounting Policies | 16
| Note 2. Rate and Regulatory Matters | 17
| Note 3. Short-term Debt and Liquidity | 21
| Note 4. Long-term Debt and Equity Financings | 22
| Note 5. Other Income, Net | 24
| Note 6. Derivative Financial Instruments | 24
| Note 7. Fair Value Measurements | 26
| Note 8. Related-party Transactions | 29
| Note 9. Commitments and Contingencies | 30
| Note 10. Callaway Energy Center | 33
| Note 11. Retirement Benefits | 34
| Note 12. Income Taxes | 35
| Note 13. Supplemental Information | 36
| Note 14. Segment Information | 39
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 43
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 79
Item 4. | Controls and Procedures | 80
PART II. Other Information |
Item 1. | Legal Proceedings | 80
Item 1A. | Risk Factors | 80
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 80
Item 5. | Other Information | 80
Item 6. | Exhibits | 81
Signatures | 82

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GLOSSARY OF TERMS AND ABBREVIATIONS
We use the words “our,” “we” or “us” with respect to certain information that relates to Ameren, Ameren Missouri, and Ameren Illinois, collectively. When appropriate, subsidiaries of Ameren Corporation are named specifically as their various business activities are discussed. Refer to the Form 10-K for a complete listing of glossary terms and abbreviations. Only new or significantly changed terms and abbreviations are included below.
Form 10-K – The combined Annual Report on Form 10-K for the year ended December 31, 2023, filed by the Ameren Companies with the SEC.
QTD – Three months ended September 30.
YTD – Nine months ended September 30.
YoY – Compared with the year-ago period.

FORWARD-LOOKING STATEMENTS
Statements in this report not based on historical facts are considered “forward-looking” and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such forward-looking statements have been made in good faith and are based on reasonable assumptions, there is no assurance that the expected results will be achieved. These statements include (without limitation) statements as to future expectations, beliefs, plans, projections, strategies, targets, estimates, objectives, events, conditions, and financial performance. In connection with the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause actual results to differ materially from those anticipated. The following factors, in addition to those discussed within Risk Factors in the Form 10-K, and elsewhere in this report and in our other filings with the SEC, could cause actual results to differ materially from management expectations suggested in such forward-looking statements:
•regulatory, judicial, or legislative actions, and any changes in regulatory policies and ratemaking determinations, that may change regulatory recovery mechanisms, such as those that may result from any additional mitigation relief related to the operation of the Rush Island Energy Center that may be ordered by the United States District Court for the Eastern District of Missouri, Ameren Missouri’s electric service regulatory rate review filed with the MoPSC in June 2024, Ameren Missouri’s natural gas delivery service regulatory rate review filed with the MoPSC in September 2024, the nonunanimous stipulation and agreement between Ameren Missouri, the MoOPC, and other intervenors related to a customer energy-efficiency plan under the MEEIA filed with the MoPSC in October 2024, Ameren Illinois’ December 2023 ICC order for the MYRP electric distribution service regulatory rate review that directed Ameren Illinois to file a revised Grid Plan and a request to update the associated MYRP revenue requirements for 2024 through 2027, both subsequently filed in March 2024, along with the appeal of the December 2023 order and June 2024 rehearing order to the Illinois Appellate Court for the Fifth Judicial District, Ameren Illinois’ electric distribution service revenue requirement reconciliation adjustment request filed with the ICC in April 2024, Ameren Illinois’ appeal of the November 2023 ICC natural gas delivery service rate order to the Illinois Appellate Court for the Fifth Judicial District, and the October 2024 FERC order regarding the allowed base ROE under the MISO tariff;
•our ability to control costs and make substantial investments in our businesses, including our ability to recover costs and investments, and to earn our allowed ROEs, within frameworks established by our regulators, while maintaining affordability of services for our customers;
•the effect and duration of Ameren Illinois’ election to utilize MYRPs for electric distribution service ratemaking effective for rates beginning in 2024, including the effect of the reconciliation cap on the electric distribution revenue requirement;
•the effect of Ameren Illinois’ use of the performance-based formula ratemaking framework for its participation in electric energy-efficiency programs, and the related impact of the direct relationship between Ameren Illinois’ ROE and the 30-year United States Treasury bond yields;
•the effect on Ameren Missouri of any customer rate caps or limitations on increasing the electric service revenue requirement pursuant to Ameren Missouri’s election to use the PISA;
•Ameren Missouri’s ability to construct and/or acquire wind, solar, and other renewable energy generation facilities and battery storage, as well as natural gas-fired energy centers, extend the operating license for the Callaway Energy Center, retire fossil fuel-fired energy centers, and implement new or existing customer energy-efficiency programs, including any such construction, acquisition, retirement, or implementation in connection with its Smart Energy Plan, integrated resource plan, or emissions reduction goals, and to recover its cost of investment, a related return, and, in the case of customer energy-efficiency programs, any lost electric revenues in a timely manner, each of which is affected by the ability to obtain all necessary regulatory and project approvals, including CCNs from the MoPSC or any other required approvals for the addition of renewable resources and natural gas-fired energy centers;
•Ameren Missouri’s ability to use or transfer federal production and investment tax credits related to renewable energy projects; the cost of wind, solar, and other renewable generation and battery storage technologies; and our ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost for each facility;
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•the outcome of competitive bids related to requests for proposals and project approvals, including CCNs from the MoPSC and the ICC or any other required approvals, associated with the MISO’s long-range transmission planning;
•the inability of our counterparties to meet their obligations with respect to contracts, credit agreements, and financial instruments, including as they relate to the construction and acquisition of electric and natural gas utility infrastructure and the ability of counterparties to complete projects, which is dependent upon the availability of necessary materials and equipment, including those obligations that are affected by supply chain disruptions;
•advancements in energy technologies, including carbon capture, utilization, and sequestration, hydrogen fuel for electric production and energy storage, next generation nuclear, and large-scale long-cycle battery energy storage, and the impact of federal and state energy and economic policies with respect to those technologies;
•the effects of changes in federal, state, or local laws and other governmental actions, including monetary, fiscal, foreign trade, and energy policies;
•the effects of changes in federal, state, or local tax laws or rates, including the effects of the IRA and the 15% minimum tax on adjusted financial statement income, as well as additional regulations, interpretations, amendments, or technical corrections to or in connection with the IRA, and challenges to the tax positions taken by the Ameren Companies, if any, as well as resulting effects on customer rates and the recoverability of the minimum tax imposed under the IRA;
•the effects on energy prices and demand for our services resulting from customer growth patterns or usage, technological advances, including advances in customer energy efficiency, electric vehicles, electrification of various industries, energy storage, and private generation sources, which generate electricity at the site of consumption and are becoming more cost-competitive;
•the cost and availability of fuel, such as low-sulfur coal, natural gas, and enriched uranium used to produce electricity; the cost and availability of natural gas for distribution and the cost and availability of purchased power, including capacity, zero emission credits, renewable energy credits, and emission allowances; and the level and volatility of future market prices for such commodities and credits;
•disruptions in the delivery of fuel, failure of our fuel suppliers to provide adequate quantities or quality of fuel, or lack of adequate inventories of fuel, including nuclear fuel assemblies primarily from the one NRC-licensed supplier of assemblies for Ameren Missouri’s Callaway Energy Center;
•the cost and availability of transmission capacity for the energy generated by Ameren Missouri’s energy centers or as required to satisfy our energy sales;
•the effectiveness of our risk management strategies and our use of financial and derivative instruments;
•the ability to obtain sufficient insurance, or, in the absence of insurance, the ability to timely recover uninsured losses from our customers;
•the impact of cyberattacks and data security risks on us, our suppliers, or other entities on the grid, which could, among other things, result in the loss of operational control of energy centers and electric and natural gas transmission and distribution systems and/or the loss of data, such as customer, employee, financial, and operating system information;
•acts of sabotage, which have increased in frequency and severity within the utility industry, war, terrorism, or other intentionally disruptive acts;
•business, economic, and capital market conditions, including the impact of such conditions on interest rates, inflation, and investments;
•the impact of inflation or a recession on our customers and the related impact on our results of operations, financial position, and liquidity;
•disruptions of the capital and credit markets, deterioration in credit metrics of the Ameren Companies, or other events that may have an adverse effect on the cost or availability of capital, including short-term credit and liquidity, and our ability to access the capital and credit markets on reasonable terms when needed;
•the actions of credit rating agencies and the effects of such actions;
•the impact of weather conditions and other natural conditions on us and our customers, including the impact of system outages and the level of wind and solar resources;
•the construction, installation, performance, and cost recovery of generation, transmission, and distribution assets;
•the ability to maintain system reliability during the transition to clean energy generation by Ameren Missouri and the electric utility industry, as well as Ameren Missouri’s ability to meet generation capacity obligations;
•the effects of failures of electric generation, electric and natural gas transmission or distribution, or natural gas storage facilities systems and equipment, which could result in unanticipated liabilities or unplanned outages;
•the operation of Ameren Missouri’s Callaway Energy Center, including planned and unplanned outages, as well as the ability to recover costs associated with such outages and the impact of such outages on off-system sales and purchased power, among other things;
•Ameren Missouri’s ability to recover the remaining investment and decommissioning costs associated with the retirement of an energy center, as well as the ability to earn a return on that remaining investment and those decommissioning costs;
•the impact of current environmental laws or their interpretation and new, more stringent, or changing requirements, including those related to NSR, CO 2, NO x, and other emissions and discharges, Illinois emission standards, cooling water intake structures, CCR, energy efficiency, and wildlife protection, that could limit or terminate the operation of certain of Ameren Missouri’s energy centers, increase our operating costs or investment requirements, result in an impairment of our assets, cause us to sell our assets, reduce our customers’ demand for electricity or natural gas, or otherwise have a negative financial effect;
•the impact of complying with renewable energy standards in Missouri and Illinois and with the zero emission standard in Illinois;
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•the effectiveness of Ameren Missouri’s customer energy-efficiency programs and the related revenues and performance incentives earned under its MEEIA programs;
•Ameren Illinois’ ability to achieve the performance standards applicable to its electric distribution business and electric customer energy-efficiency goals and the resulting impact on its allowed ROE;
•labor disputes, work force reductions, our ability to retain professional and skilled-craft employees, changes in future wage and employee benefits costs, including those resulting from changes in discount rates, mortality tables, returns on benefit plan assets, and other assumptions;
•the impact of negative opinions of us or our utility services that our customers, investors, legislators, regulators, creditors, or other stakeholders may have or develop, which could result from a variety of factors, including failures in system reliability, failure to implement our investment plans or to protect sensitive customer information, increases in rates, negative media coverage, or concerns about ESG practices;
•the impact of adopting new accounting and reporting guidance;
•the effects of strategic initiatives, including mergers, acquisitions, and divestitures;
•legal and administrative proceedings;
•pandemics or other significant global health events, and their impacts on our results of operations, financial position, and liquidity; and
•the impacts of the Russian invasion of Ukraine and conflicts in the Middle East, related sanctions imposed by the United States and other governments, and any broadening of these or other global conflicts, including potential impacts on the cost and availability of fuel, natural gas, enriched uranium, and other commodities, materials, and services, the inability of our counterparties to perform their obligations, disruptions in the capital and credit markets, acts of sabotage or terrorism, including cyberattacks, and other impacts on business, economic, and geopolitical conditions, including inflation.
New factors emerge from time to time, and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement. Given these uncertainties, undue reliance should not be placed on these forward-looking statements. Except to the extent required by the federal securities laws, we undertake no obligation to update or revise publicly any forward-looking statements to reflect new information or future events.
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PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
AMEREN CORPORATION
CONSOLIDATED STATEMENT OF INCOME AND COMPREHENSIVE INCOME
(Unaudited) (In millions, except per share amounts)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues: |  |  |  |  |  |  |
Electric | $ | 2,035 |  |  | $ | 1,921 |  |  | $ | 4,920 |  |  | $ | 5,096 |
Natural gas | 138 |  |  | 139 |  |  | 762 |  |  | 786 |
Total operating revenues | 2,173 |  |  | 2,060 |  |  | 5,682 |  |  | 5,882 |
Operating Expenses: |  |  |  |  |  |  |
Fuel and purchased power | 499 |  |  | 430 |  |  | 1,154 |  |  | 1,518 |
Natural gas purchased for resale | 30 |  |  | 30 |  |  | 214 |  |  | 280 |
Other operations and maintenance | 520 |  |  | 470 |  |  | 1,455 |  |  | 1,368 |
Depreciation and amortization | 388 |  |  | 369 |  |  | 1,125 |  |  | 1,024 |
Taxes other than income taxes | 150 |  |  | 147 |  |  | 416 |  |  | 398 |
Total operating expenses | 1,587 |  |  | 1,446 |  |  | 4,364 |  |  | 4,588 |
Operating Income | 586 |  |  | 614 |  |  | 1,318 |  |  | 1,294 |
Other Income, Net | 101 |  |  | 101 |  |  | 293 |  |  | 261 |
Interest Charges | 173 |  |  | 152 |  |  | 492 |  |  | 413 |
Income Before Income Taxes | 514 |  |  | 563 |  |  | 1,119 |  |  | 1,142 |
Income Taxes | 57 |  |  | 69 |  |  | 140 |  |  | 144 |
Net Income | 457 |  |  | 494 |  |  | 979 |  |  | 998 |
Less: Net Income Attributable to Noncontrolling Interests | 1 |  |  | 1 |  |  | 4 |  |  | 4 |
Net Income Attributable to Ameren Common Shareholders | $ | 456 |  |  | $ | 493 |  |  | $ | 975 |  |  | $ | 994 |
Net Income | $ | 457 |  |  | $ | 494 |  |  | $ | 979 |  |  | $ | 998 |
Other Comprehensive Loss, Net of Taxes |  |  |  |  |  |  |
Pension and other postretirement benefit plan activity, net of income taxes (benefit) of $—, $(1), $(1), and $(1), respectively | (1) |  |  | (1) |  |  | (4) |  |  | (3) |
Comprehensive Income | 456 |  |  | 493 |  |  | 975 |  |  | 995 |
Less: Comprehensive Income Attributable to Noncontrolling Interests | 1 |  |  | 1 |  |  | 4 |  |  | 4 |
Comprehensive Income Attributable to Ameren Common Shareholders | $ | 455 |  |  | $ | 492 |  |  | $ | 971 |  |  | $ | 991 |
Earnings per Common Share – Basic | $ | 1.71 |  |  | $ | 1.88 |  |  | $ | 3.66 |  |  | $ | 3.79 |
Earnings per Common Share – Diluted | $ | 1.70 |  |  | $ | 1.87 |  |  | $ | 3.65 |  |  | $ | 3.78 |
Weighted-average Common Shares Outstanding – Basic | 266.8 |  |  | 262.8 |  |  | 266.6 |  |  | 262.5 |
Weighted-average Common Shares Outstanding – Diluted | 267.3 |  |  | 263.4 |  |  | 266.9 |  |  | 263.2 |

The accompanying notes are an integral part of these consolidated financial statements.
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AMEREN CORPORATION
CONSOLIDATED BALANCE SHEET
(Unaudited) (In millions, except per share amounts)

| September 30, 2024 |  | December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash and cash equivalents | $ | 17 |  |  | $ | 25 |
Accounts receivable – trade (less allowance for doubtful accounts of $31 and $30, respectively) | 651 |  |  | 494 |
Unbilled revenue | 348 |  |  | 319 |
Miscellaneous accounts receivable | 70 |  |  | 106 |
Inventories | 792 |  |  | 733 |
Current regulatory assets | 226 |  |  | 365 |
Other current assets | 153 |  |  | 139 |
Total current assets | 2,257 |  |  | 2,181 |
Property, Plant, and Equipment, Net | 35,720 |  |  | 33,776 |
Investments and Other Assets: |  |  |
Nuclear decommissioning trust fund | 1,333 |  |  | 1,150 |
Goodwill | 411 |  |  | 411 |
Regulatory assets | 1,915 |  |  | 1,810 |
Pension and other postretirement benefits | 581 |  |  | 581 |
Other assets | 1,081 |  |  | 921 |
Total investments and other assets | 5,321 |  |  | 4,873 |
TOTAL ASSETS | $ | 43,298 |  |  | $ | 40,830 |
LIABILITIES AND EQUITY |  |  |
Current Liabilities: |  |  |
Current maturities of long-term debt | $ | 300 |  |  | $ | 849 |
Short-term debt | 1,539 |  |  | 536 |
Accounts and wages payable | 717 |  |  | 1,136 |
Taxes accrued | 206 |  |  | 54 |
Customer deposits | 205 |  |  | 176 |
Other current liabilities | 600 |  |  | 594 |
Total current liabilities | 3,567 |  |  | 3,345 |
Long-term Debt, Net | 16,422 |  |  | 15,121 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated deferred income taxes and tax credits, net | 4,477 |  |  | 4,176 |
Regulatory liabilities | 5,562 |  |  | 5,512 |
Asset retirement obligations | 798 |  |  | 772 |
Other deferred credits and liabilities | 510 |  |  | 426 |
Total deferred credits and other liabilities | 11,347 |  |  | 10,886 |
Commitments and Contingencies (Notes 2, 9, and 10) |  |  |
Shareholders’ Equity: |  |  |
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 266.9 and 266.3, respectively | 3 |  |  | 3 |
Other paid-in capital, principally premium on common stock | 7,264 |  |  | 7,216 |
Retained earnings | 4,576 |  |  | 4,136 |
Accumulated other comprehensive loss | (10) |  |  | (6) |
Total shareholders’ equity | 11,833 |  |  | 11,349 |
Noncontrolling Interests | 129 |  |  | 129 |
Total equity | 11,962 |  |  | 11,478 |
TOTAL LIABILITIES AND EQUITY | $ | 43,298 |  |  | $ | 40,830 |

The accompanying notes are an integral part of these consolidated financial statements.
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AMEREN CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited) (In millions)
| Nine Months Ended September 30,
| 2024 |  | 2023
Cash Flows From Operating Activities: |  |  |
Net income | $ | 979 |  |  | $ | 998 |
Adjustments to reconcile net income to net cash provided by operating activities: |  |  |
Depreciation and amortization | 1,142 |  |  | 1,063 |
Amortization of nuclear fuel | 59 |  |  | 56 |
Amortization of debt issuance costs and premium/discounts | 14 |  |  | 12 |
Deferred income taxes and investment tax credits, net | 145 |  |  | 128 |
Allowance for equity funds used during construction | (48) |  |  | (39) |
Stock-based compensation costs | 22 |  |  | 21 |
Other | 84 |  |  | 12 |
Changes in assets and liabilities: |  |  |
Receivables | (183) |  |  | 54 |
Inventories | (60) |  |  | (93) |
Accounts and wages payable | (239) |  |  | (287) |
Taxes accrued | 176 |  |  | 156 |
Regulatory assets and liabilities | 86 |  |  | 15 |
Assets, other | (53) |  |  | (78) |
Liabilities, other | (11) |  |  | 51 |
Pension and other postretirement benefits | (168) |  |  | (182) |
Counterparty collateral, net | 1 |  |  | 144 |
Net cash provided by operating activities | 1,946 |  |  | 2,031 |
Cash Flows From Investing Activities: |  |  |
Capital expenditures | (3,029) |  |  | (2,571) |
Nuclear fuel expenditures | (57) |  |  | (63) |
Purchases of securities – nuclear decommissioning trust fund | (499) |  |  | (156) |
Sales and maturities of securities – nuclear decommissioning trust fund | 480 |  |  | 136 |
Other | (1) |  |  | (2) |
Net cash used in investing activities | (3,106) |  |  | (2,656) |
Cash Flows From Financing Activities: |  |  |
Dividends on common stock | (535) |  |  | (496) |
Dividends paid to noncontrolling interest holders | (4) |  |  | (4) |
Short-term debt, net | 1,002 |  |  | 272 |
Maturities of long-term debt | (849) |  |  | (100) |
Issuances of long-term debt | 1,610 |  |  | 997 |
Issuances of common stock | 30 |  |  | 28 |
Employee payroll taxes related to stock-based compensation | (8) |  |  | (20) |
Debt issuance costs | (19) |  |  | (12) |
Other | (15) |  |  | (10) |
Net cash provided by financing activities | 1,212 |  |  | 655 |
Net change in cash, cash equivalents, and restricted cash | 52 |  |  | 30 |
Cash, cash equivalents, and restricted cash at beginning of year | 272 |  |  | 216 |
Cash, cash equivalents, and restricted cash at end of period | $ | 324 |  |  | $ | 246 |

The accompanying notes are an integral part of these consolidated financial statements.
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AMEREN CORPORATION
CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY
(Unaudited) (In millions, except per share amounts)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Common Stock | $ | 3 |  |  | $ | 3 |  |  | $ | 3 |  |  | $ | 3 |
Other Paid-in Capital: |  |  |  |  |  |  |
Beginning of period | 7,246 |  |  | 6,880 |  |  | 7,216 |  |  | 6,860 |
Shares issued under the DRPlus and 401(k) plan | 9 |  |  | 12 |  |  | 30 |  |  | 35 |
Stock-based compensation activity | 9 |  |  | 8 |  |  | 18 |  |  | 5 |
Other paid-in capital, end of period | 7,264 |  |  | 6,900 |  |  | 7,264 |  |  | 6,900 |
Retained Earnings: |  |  |  |  |  |  |
Beginning of period | 4,299 |  |  | 3,817 |  |  | 4,136 |  |  | 3,646 |
Net income attributable to Ameren common shareholders | 456 |  |  | 493 |  |  | 975 |  |  | 994 |
Dividends on common stock | (179) |  |  | (166) |  |  | (535) |  |  | (496) |
Retained earnings, end of period | 4,576 |  |  | 4,144 |  |  | 4,576 |  |  | 4,144 |
Accumulated Other Comprehensive Loss: |  |  |  |  |  |  |
Deferred retirement benefit costs, beginning of period | (9) |  |  | (3) |  |  | (6) |  |  | (1) |
Change in deferred retirement benefit costs | (1) |  |  | (1) |  |  | (4) |  |  | (3) |
Deferred retirement benefit costs, end of period | (10) |  |  | (4) |  |  | (10) |  |  | (4) |
Total accumulated other comprehensive loss, end of period | (10) |  |  | (4) |  |  | (10) |  |  | (4) |
Total Shareholders’ Equity | $ | 11,833 |  |  | $ | 11,043 |  |  | $ | 11,833 |  |  | $ | 11,043 |
Noncontrolling Interests: |  |  |  |  |  |  |
Beginning of period | 129 |  |  | 129 |  |  | 129 |  |  | 129 |
Net income attributable to noncontrolling interest holders | 1 |  |  | 1 |  |  | 4 |  |  | 4 |
Dividends paid to noncontrolling interest holders | (1) |  |  | (1) |  |  | (4) |  |  | (4) |
Noncontrolling interests, end of period | 129 |  |  | 129 |  |  | 129 |  |  | 129 |
Total Equity | $ | 11,962 |  |  | $ | 11,172 |  |  | $ | 11,962 |  |  | $ | 11,172 |
Common stock shares outstanding at beginning of period | 266.8 |  |  | 262.7 |  |  | 266.3 |  |  | 262.0 |
Shares issued under the DRPlus and 401(k) plan | 0.1 |  |  | 0.2 |  |  | 0.4 |  |  | 0.4 |
Shares issued for stock-based compensation | — |  |  | — |  |  | 0.2 |  |  | 0.5 |
Common stock shares outstanding at end of period | 266.9 |  |  | 262.9 |  |  | 266.9 |  |  | 262.9 |
Dividends per common share | $ | 0.67 |  |  | $ | 0.63 |  |  | $ | 2.01 |  |  | $ | 1.89 |

The accompanying notes are an integral part of these consolidated financial statements.
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UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF INCOME
(Unaudited) (In millions)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues: |  |  |  |  |  |  |
Electric | $ | 1,324 |  |  | $ | 1,219 |  |  | $ | 2,902 |  |  | $ | 2,978 |
Natural gas | 18 |  |  | 18 |  |  | 103 |  |  | 123 |
Total operating revenues | 1,342 |  |  | 1,237 |  |  | 3,005 |  |  | 3,101 |
Operating Expenses: |  |  |  |  |  |  |
Fuel and purchased power | 334 |  |  | 233 |  |  | 689 |  |  | 843 |
Natural gas purchased for resale | 4 |  |  | 4 |  |  | 41 |  |  | 60 |
Other operations and maintenance | 288 |  |  | 256 |  |  | 789 |  |  | 732 |
Depreciation and amortization | 220 |  |  | 217 |  |  | 623 |  |  | 579 |
Taxes other than income taxes | 109 |  |  | 108 |  |  | 287 |  |  | 276 |
Total operating expenses | 955 |  |  | 818 |  |  | 2,429 |  |  | 2,490 |
Operating Income | 387 |  |  | 419 |  |  | 576 |  |  | 611 |
Other Income, Net | 51 |  |  | 44 |  |  | 144 |  |  | 85 |
Interest Charges | 62 |  |  | 63 |  |  | 187 |  |  | 166 |
Income Before Income Taxes | 376 |  |  | 400 |  |  | 533 |  |  | 530 |
Income Taxes Benefit | (6) |  |  | (12) |  |  | (4) |  |  | (14) |
Net Income | 382 |  |  | 412 |  |  | 537 |  |  | 544 |
Preferred Stock Dividends | 1 |  |  | 1 |  |  | 3 |  |  | 3 |
Net Income Available to Common Shareholder | $ | 381 |  |  | $ | 411 |  |  | $ | 534 |  |  | $ | 541 |

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
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UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)
CONSOLIDATED BALANCE SHEET
(Unaudited) (In millions, except per share amounts)

| September 30, 2024 |  | December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash and cash equivalents | $ | — |  |  | $ | — |
Advances to money pool | 9 |  |  | — |
Accounts receivable – trade (less allowance for doubtful accounts of $12 and $12, respectively) | 300 |  |  | 204 |
Accounts receivable – affiliates | 22 |  |  | 72 |
Unbilled revenue | 229 |  |  | 163 |
Miscellaneous accounts receivable | 28 |  |  | 26 |
Inventories | 529 |  |  | 508 |
Current regulatory assets | 84 |  |  | 101 |
Other current assets | 65 |  |  | 68 |
Total current assets | 1,266 |  |  | 1,142 |
Property, Plant, and Equipment, Net | 18,518 |  |  | 17,250 |
Investments and Other Assets: |  |  |
Nuclear decommissioning trust fund | 1,333 |  |  | 1,150 |
Regulatory assets | 746 |  |  | 755 |
Pension and other postretirement benefits | 142 |  |  | 157 |
Other assets | 204 |  |  | 152 |
Total investments and other assets | 2,425 |  |  | 2,214 |
TOTAL ASSETS | $ | 22,209 |  |  | $ | 20,606 |
LIABILITIES AND SHAREHOLDERS’ EQUITY |  |  |
Current Liabilities: |  |  |
Current maturities of long-term debt | $ | — |  |  | $ | 350 |
Short-term debt | 576 |  |  | 170 |
Borrowings from money pool | 17 |  |  | 306 |
Accounts and wages payable | 327 |  |  | 618 |
Accounts payable – affiliates | 63 |  |  | 53 |
Taxes accrued | 184 |  |  | 28 |
Other current liabilities | 322 |  |  | 222 |
Total current liabilities | 1,489 |  |  | 1,747 |
Long-term Debt, Net | 6,830 |  |  | 5,991 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated deferred income taxes and tax credits, net | 2,208 |  |  | 2,122 |
Regulatory liabilities | 2,914 |  |  | 2,959 |
Asset retirement obligations | 795 |  |  | 768 |
Other deferred credits and liabilities | 126 |  |  | 56 |
Total deferred credits and other liabilities | 6,043 |  |  | 5,905 |
Commitments and Contingencies (Notes 2, 8, 9, and 10) |  |  |
Shareholders’ Equity: |  |  |
Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding | 511 |  |  | 511 |
Other paid-in capital, principally premium on common stock | 3,075 |  |  | 2,725 |
Preferred stock | 80 |  |  | 80 |
Retained earnings | 4,181 |  |  | 3,647 |
Total shareholders’ equity | 7,847 |  |  | 6,963 |
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $ | 22,209 |  |  | $ | 20,606 |

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
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UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited) (In millions)

| Nine Months Ended September 30,
| 2024 |  | 2023
Cash Flows From Operating Activities: |  |  |
Net income | $ | 537 |  |  | $ | 544 |
Adjustments to reconcile net income to net cash provided by operating activities: |  |  |
Depreciation and amortization | 641 |  |  | 618 |
Amortization of nuclear fuel | 59 |  |  | 56 |
Amortization of debt issuance costs and premium/discounts | 5 |  |  | 5 |
Deferred income taxes and investment tax credits, net | 2 |  |  | (73) |
Allowance for equity funds used during construction | (38) |  |  | (20) |
Other | 69 |  |  | (12) |
Changes in assets and liabilities: |  |  |
Receivables | (178) |  |  | (119) |
Inventories | (21) |  |  | (78) |
Accounts and wages payable | (223) |  |  | (206) |
Taxes accrued | 218 |  |  | 222 |
Regulatory assets and liabilities | (5) |  |  | 65 |
Assets, other | (17) |  |  | 12 |
Liabilities, other | 10 |  |  | (5) |
Pension and other postretirement benefits | (59) |  |  | (67) |
Counterparty collateral, net | (3) |  |  | 89 |
Net cash provided by operating activities | 997 |  |  | 1,031 |
Cash Flows From Investing Activities: |  |  |
Capital expenditures | (1,839) |  |  | (1,255) |
Nuclear fuel expenditures | (57) |  |  | (63) |
Purchases of securities – nuclear decommissioning trust fund | (499) |  |  | (156) |
Sales and maturities of securities – nuclear decommissioning trust fund | 480 |  |  | 136 |
Money pool advances, net | (9) |  |  | — |
Other | (8) |  |  | — |
Net cash used in investing activities | (1,932) |  |  | (1,338) |
Cash Flows From Financing Activities: |  |  |
Dividends on preferred stock | (3) |  |  | (3) |
Short-term debt, net | 406 |  |  | (172) |
Money pool borrowings, net | (289) |  |  | — |
Maturities of long-term debt | (350) |  |  | — |
Issuances of long-term debt | 846 |  |  | 499 |
Capital contribution from parent | 350 |  |  | — |
Debt issuance costs | (10) |  |  | (7) |
Other | (15) |  |  | (10) |
Net cash provided by financing activities | 935 |  |  | 307 |
Net change in cash, cash equivalents, and restricted cash | — |  |  | — |
Cash, cash equivalents, and restricted cash at beginning of year | 10 |  |  | 13 |
Cash, cash equivalents, and restricted cash at end of period | $ | 10 |  |  | $ | 13 |

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
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UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY
(Unaudited) (In millions)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Common Stock | $ | 511 |  |  | $ | 511 |  |  | $ | 511 |  |  | $ | 511 |
Other Paid-in Capital: |  |  |  |  |  |  |
Beginning of period | 3,075 |  |  | 2,725 |  |  | 2,725 |  |  | 2,725 |
Capital contributions from parent | — |  |  | — |  |  | 350 |  |  | — |
Other paid-in capital, end of period | 3,075 |  |  | 2,725 |  |  | 3,075 |  |  | 2,725 |
Preferred Stock | 80 |  |  | 80 |  |  | 80 |  |  | 80 |
Retained Earnings: |  |  |  |  |  |  |
Beginning of period | 3,800 |  |  | 3,241 |  |  | 3,647 |  |  | 3,111 |
Net income | 382 |  |  | 412 |  |  | 537 |  |  | 544 |
Dividends on preferred stock | (1) |  |  | (1) |  |  | (3) |  |  | (3) |
Retained earnings, end of period | 4,181 |  |  | 3,652 |  |  | 4,181 |  |  | 3,652 |
Total Shareholders’ Equity | $ | 7,847 |  |  | $ | 6,968 |  |  | $ | 7,847 |  |  | $ | 6,968 |

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
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AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS)
STATEMENT OF INCOME
(Unaudited) (In millions)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues: |  |  |  |  |  |  |
Electric | $ | 672 |  |  | $ | 661 |  |  | $ | 1,899 |  |  | $ | 1,998 |
Natural gas | 121 |  |  | 122 |  |  | 660 |  |  | 665 |
Total operating revenues | 793 |  |  | 783 |  |  | 2,559 |  |  | 2,663 |
Operating Expenses: |  |  |  |  |  |  |
Purchased power | 169 |  |  | 200 |  |  | 474 |  |  | 679 |
Natural gas purchased for resale | 26 |  |  | 26 |  |  | 173 |  |  | 220 |
Other operations and maintenance | 229 |  |  | 200 |  |  | 663 |  |  | 603 |
Depreciation and amortization | 155 |  |  | 139 |  |  | 462 |  |  | 410 |
Taxes other than income taxes | 37 |  |  | 34 |  |  | 116 |  |  | 108 |
Total operating expenses | 616 |  |  | 599 |  |  | 1,888 |  |  | 2,020 |
Operating Income | 177 |  |  | 184 |  |  | 671 |  |  | 643 |
Other Income, Net | 37 |  |  | 37 |  |  | 105 |  |  | 115 |
Interest Charges | 63 |  |  | 54 |  |  | 178 |  |  | 151 |
Income Before Income Taxes | 151 |  |  | 167 |  |  | 598 |  |  | 607 |
Income Taxes | 37 |  |  | 42 |  |  | 144 |  |  | 154 |
Net Income | 114 |  |  | 125 |  |  | 454 |  |  | 453 |
Preferred Stock Dividends | — |  |  | — |  |  | 1 |  |  | 1 |
Net Income Available to Common Shareholder | $ | 114 |  |  | $ | 125 |  |  | $ | 453 |  |  | $ | 452 |

The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS)
BALANCE SHEET
(Unaudited) (In millions)

| September 30, 2024 |  | December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash and cash equivalents | $ | — |  |  | $ | — |
Accounts receivable – trade (less allowance for doubtful accounts of $19 and $18, respectively) | 336 |  |  | 273 |
Accounts receivable – affiliates | 17 |  |  | 35 |
Unbilled revenue | 119 |  |  | 156 |
Miscellaneous accounts receivable | 7 |  |  | 44 |
Inventories | 260 |  |  | 225 |
Current regulatory assets | 139 |  |  | 252 |
Other current assets | 66 |  |  | 62 |
Total current assets | 944 |  |  | 1,047 |
Property, Plant, and Equipment, Net | 15,247 |  |  | 14,632 |
Investments and Other Assets: |  |  |
Goodwill | 411 |  |  | 411 |
Regulatory assets | 1,135 |  |  | 1,035 |
Pension and other postretirement benefits | 419 |  |  | 394 |
Other assets | 679 |  |  | 603 |
Total investments and other assets | 2,644 |  |  | 2,443 |
TOTAL ASSETS | $ | 18,835 |  |  | $ | 18,122 |
LIABILITIES AND SHAREHOLDERS’ EQUITY |  |  |
Current Liabilities: |  |  |
Current maturities of long-term debt | $ | 300 |  |  | $ | — |
Short-term debt | 17 |  |  | 366 |
Borrowings from money pool | — |  |  | 135 |
Accounts and wages payable | 283 |  |  | 370 |
Accounts payable – affiliates | 147 |  |  | 52 |
Customer deposits | 166 |  |  | 141 |
Current regulatory liabilities | 50 |  |  | 71 |
Other current liabilities | 230 |  |  | 298 |
Total current liabilities | 1,193 |  |  | 1,433 |
Long-term Debt, Net | 5,552 |  |  | 5,232 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated deferred income taxes and investment tax credits, net | 2,012 |  |  | 1,906 |
Regulatory liabilities | 2,504 |  |  | 2,418 |
Other deferred credits and liabilities | 346 |  |  | 308 |
Total deferred credits and other liabilities | 4,862 |  |  | 4,632 |
Commitments and Contingencies (Notes 2, 8, and 9) |  |  |
Shareholders’ Equity: |  |  |
Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding | — |  |  | — |
Other paid-in capital | 3,020 |  |  | 3,020 |
Preferred stock | 49 |  |  | 49 |
Retained earnings | 4,159 |  |  | 3,756 |
Total shareholders’ equity | 7,228 |  |  | 6,825 |
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $ | 18,835 |  |  | $ | 18,122 |

The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS)
STATEMENT OF CASH FLOWS
(Unaudited) (In millions)

| Nine Months Ended September 30,
| 2024 |  | 2023
Cash Flows From Operating Activities: |  |  |
Net income | $ | 454 |  |  | $ | 453 |
Adjustments to reconcile net income to net cash provided by operating activities: |  |  |
Depreciation and amortization | 461 |  |  | 410 |
Amortization of debt issuance costs and premium/discounts | 3 |  |  | 3 |
Deferred income taxes and investment tax credits, net | 72 |  |  | 123 |
Allowance for equity funds used during construction | (10) |  |  | (15) |
Other | 32 |  |  | 31 |
Changes in assets and liabilities: |  |  |
Receivables | (23) |  |  | 164 |
Inventories | (35) |  |  | (15) |
Accounts and wages payable | (8) |  |  | (77) |
Taxes accrued | 118 |  |  | 19 |
Regulatory assets and liabilities | 96 |  |  | (45) |
Assets, other | (38) |  |  | (80) |
Liabilities, other | (2) |  |  | 74 |
Pension and other postretirement benefits | (66) |  |  | (74) |
Counterparty collateral, net | 13 |  |  | 55 |
Net cash provided by operating activities | 1,067 |  |  | 1,026 |
Cash Flows From Investing Activities: |  |  |
Capital expenditures | (1,091) |  |  | (1,226) |
Other | 1 |  |  | (3) |
Net cash used in investing activities | (1,090) |  |  | (1,229) |
Cash Flows From Financing Activities: |  |  |
Dividends on common stock | (50) |  |  | — |
Dividends on preferred stock | (1) |  |  | (1) |
Short-term debt, net | (349) |  |  | (205) |
Money pool borrowings, net | (135) |  |  | — |
Maturities of long-term debt | — |  |  | (100) |
Issuances of long-term debt | 624 |  |  | 498 |
Capital contributions from parent | — |  |  | 50 |
Debt issuance costs | (7) |  |  | (5) |
Net cash provided by financing activities | 82 |  |  | 237 |
Net change in cash, cash equivalents, and restricted cash | 59 |  |  | 34 |
Cash, cash equivalents and restricted cash at beginning of year | 234 |  |  | 191 |
Cash, cash equivalents, and restricted cash at end of period | $ | 293 |  |  | $ | 225 |

The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS)
STATEMENT OF SHAREHOLDERS’ EQUITY
(Unaudited) (In millions)

| Three Months Ended September 30, |  | Nine Months Ended September 30,
| 2024 |  | 2023 |  | 2024 |  | 2023
Common Stock | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |
Other Paid-in Capital: |  |  |  |  |  |  |
Beginning of period | 3,020 |  |  | 2,929 |  |  | 3,020 |  |  | 2,929 |
Capital contributions from parent | — |  |  | 50 |  |  | — |  |  | 50 |
Other paid-in capital, end of period | 3,020 |  |  | 2,979 |  |  | 3,020 |  |  | 2,979 |
Preferred Stock | 49 |  |  | 49 |  |  | 49 |  |  | 49 |
Retained Earnings: |  |  |  |  |  |  |
Beginning of period | 4,070 |  |  | 3,517 |  |  | 3,756 |  |  | 3,190 |
Net income | 114 |  |  | 125 |  |  | 454 |  |  | 453 |
Dividends on common stock | (25) |  |  | — |  |  | (50) |  |  | — |
Dividends on preferred stock | — |  |  | — |  |  | (1) |  |  | (1) |
Retained earnings, end of period | 4,159 |  |  | 3,642 |  |  | 4,159 |  |  | 3,642 |
Total Shareholders’ Equity | $ | 7,228 |  |  | $ | 6,670 |  |  | $ | 7,228 |  |  | $ | 6,670 |

The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN CORPORATION (Consolidated)
UNION ELECTRIC COMPANY (Consolidated) (d/b/a Ameren Missouri)
AMEREN ILLINOIS COMPANY (d/b/a Ameren Illinois)
COMBINED NOTES TO FINANCIAL STATEMENTS
(Unaudited)
September 30, 2024
NOTE 1 – 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 within 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 September 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 $74 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 September 30, 2024, Ameren’s maximum exposure to loss related to these variable interests is limited to its investment of $74 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 September 30, 2024, the cash surrender value of COLI at Ameren and Ameren Illinois was $263 million (December 31, 2023 – $248 million) and $116 million (December 31, 2023 – $111 million), respectively, while total borrowings against the policies were $108 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.
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NOTE 2 – 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% ROE, 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 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 2023 IRP, 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.
2024 Natural Gas Delivery Service Regulatory Rate Review
In September 2024, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for natural gas delivery service by $40 million. The natural gas rate increase request is based on a 10.25% ROE, a capital structure composed of 52% common equity, a rate base of $531 million, and a test year ended March 31, 2024, with certain pro-forma adjustments expected through the true-up date of December 31, 2024. The request includes the continued use of the PGA, WNAR, and trackers for pension and other postretirement benefits and certain excess deferred taxes that the MoPSC previously authorized in earlier natural gas rate orders. The natural gas rate increase request reflects investments in our existing natural gas infrastructure to ensure the safe delivery of natural gas.
The MoPSC proceeding relating to the proposed natural gas delivery service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by August 2025 and new rates effective by September 2025. Ameren Missouri cannot predict the level of any natural gas delivery 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.
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Generation Facilities
Ameren Missouri, and certain subsidiaries of Ameren Missouri, are parties to agreements to acquire and/or construct various generation facilities. The solar generation facilities are eligible for recovery under the PISA. The Castle Bluff Natural Gas Project would be eligible for recovery under the post-construction cost deferral discussed below, if approved by the MoPSC. 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
Cass County Solar Project(c)(d) | Development-transfer(e) | 150-MW | Approved June 2024 | Not applicable | Fourth quarter 2024
Vandalia Solar Project(f)(g) | Self-build | 50-MW | Approved March 2024 | Not applicable | Fourth quarter 2025
Bowling Green Solar Project(f)(g) | Self-build | 50-MW | Approved March 2024 | Not applicable | First quarter 2026
Split Rail Solar Project(f)(g) | Build-transfer | 300-MW | Approved March 2024 | Received November 2024 | Mid-2026
Castle Bluff Natural Gas Project(f) | Self-build | 800-MW | Approved October 2024(h) | Not applicable | Fourth quarter 2027

(a)Anticipated in-service dates are dependent on the timing of 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 are eligible for recovery under the RESRAM.
(c)Ameren Missouri acquired the Cass County, Boomtown, and Huck Finn solar projects in June 2024, September 2024, and October 2024, respectively. These three acquisitions collectively represent a purchase price of approximately $0.9 billion.
(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)The development-transfer agreement included solar panels, project design, land rights, and engineering, procurement, and construction agreements. Ameren Missouri took over construction management of the project when it was acquired in June 2024.
(f)These projects collectively represent approximately $1.7 billion of expected capital expenditures.
(g)These solar projects are expected to support Ameren Missouri’s transition to renewable energy generation.
(h)For additional information see Castle Bluff Natural Gas Project CCN and Post-Construction Cost Deferral below.
Castle Bluff Natural Gas Project CCN and Post-Construction Cost Deferral
In October 2024, the MoPSC issued an order approving a nonunanimous stipulation and agreement filed by Ameren Missouri, the MoPSC staff, and other intervenors requesting a CCN for the Castle Bluff Natural Gas Project. The order also includes the use of a post-construction cost deferral related to the Castle Bluff Natural Gas Project, which allows Ameren Missouri to defer and recover depreciation expense, financing costs, and applicable income taxes incurred from the date the project is placed in service to the date when project costs are reflected in updated base rates as a result of a regulatory rate review. The period of deferral would be limited to the earlier of the time the project costs are reflected in base rates or six months.
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 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 September 2024, the financing order became final and unappealable.
MEEIA
In January 2024, Ameren Missouri filed a proposed customer energy-efficiency plan with the MoPSC under the MEEIA. In October 2024, Ameren Missouri, the MoOPC, and other intervenors filed a nonunanimous stipulation and agreement with the MoPSC for a three-year plan, which includes a portfolio of customer energy-efficiency and demand response programs, along with the continued use of the MEEIA rider,
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which allows Ameren Missouri to collect from customers its actual MEEIA program costs and related lost electric revenues. If the agreement is approved, Ameren Missouri intends to invest $51 million annually in 2025 and 2026 and $22 million in 2027 in the proposed customer energy-efficiency and demand response programs. In addition, the agreement requested performance incentives applicable to each plan year to earn revenues by achieving certain spending and demand response goals. If 100% of the goals are achieved in 2025, 2026, and 2027, Ameren Missouri would earn performance incentive revenues of $5 million, $5 million, and $2 million, respectively. Ameren Missouri expects a decision by the MoPSC in the fourth quarter of 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 expects to 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. Also, in January 2024, Ameren Illinois filed an appeal of the December 2023 ICC order, including the 8.72% ROE, and subsequently updated the appeal filing in September 2024 to include the June 2024 rehearing order regarding the inclusion of an asset associated with other postretirement benefits in the rate base to the Illinois Appellate Court for the Fifth Judicial District. The court is under no deadline to address the appeal.
In September 2024, Ameren Illinois filed an update to its revised Grid Plan and revised MYRP to update the requested revenue requirements for 2024 through 2027. Related to this MYRP filing, the ICC staff submitted its recommendation, and the administrative law judges issued a proposed order in August 2024 and October 2024, respectively, each recommending ICC approval of the Grid Plan and MYRP, with various adjustments as outlined in the table below. An ICC decision on the revised Grid Plan and updated revenue requirements is expected in December 2024 with rates effective in January 2025.
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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’ September 2024 revised MYRP, the ICC staff’s August 2024 revised MYRP recommendation, and the October 2024 administrative law judges’ proposed order:

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’ September 2024 Revised MYRP(a): |  |  |  |
2024 | $1,215 |  |  | $4.3
2025 | $1,299 |  |  | $4.5
2026 | $1,385 |  |  | $4.8
2027 | $1,444 |  |  | $5.0
ICC Staff’s August 2024 Revised MYRP(a): |  |  |  |
2024 | $1,206 |  |  | $4.2
2025 | $1,288 |  |  | $4.4
2026 | $1,369 |  |  | $4.6
2027 | $1,424 |  |  | $4.8
Administrative Law Judges’ October 2024 Proposed Order(a): |  |  |  |
2024 | $1,206 |  |  | $4.2
2025 | $1,287 |  |  | $4.4
2026 | $1,370 |  |  | $4.6
2027 | $1,427 |  |  | $4.9

(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 $332 million in Ameren Illinois’ September 2024 revised MYRP, a cumulative increase of $311 million in the ICC staff’s August 2024 revised MYRP recommendation, and a cumulative increase of $315 million in the administrative law judges’ October 2024 proposed order.
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 August 2024, the ICC staff submitted its calculation of the reconciliation adjustment, recommending approval of Ameren Illinois’ request. 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. In September 2024, the ICC staff filed a recommendation supporting Ameren Illinois’ requested increase. 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
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$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 September 2024, the Illinois Attorney General’s office challenged the recovery of capital investments that were made during 2020, alleging that the ICC should disallow approximately $30 million in natural gas capital investments as improper and imprudent, and resulting in a potential over-recovery of approximately $1 million by Ameren Illinois in 2020. In October 2023, and again in September 2024, 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 from 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. In October 2024, the FERC issued an order, which decreased the allowed base ROE from 10.02% to 9.98% and required refunds, with interest, for the same periods covered by the May 2020 order.
As a result of the October 2024 order, Ameren and Ameren Illinois recognized reductions to "Operating Revenues – Electric" on their statements of income of $10 million and $7 million, respectively, and recognized expense of $2 million and $1 million, respectively, in “Interest charges” on their statements of income during the third quarter of 2024. As of September 30, 2024, Ameren and Ameren Illinois had recorded liabilities in "Current regulatory liabilities" on their balance sheets of $12 million and $8 million, respectively, to reflect the expected refunds, including interest, associated with the allowed base ROE set by the October 2024 order. The decrease in the FERC-allowed base ROE resulting from the October 2024 order is not material to Ameren Missouri’s results of operations, financial position, or liquidity.
NOTE 3 – SHORT-TERM DEBT AND LIQUIDITY
The liquidity needs of the Ameren Companies are 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.
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Short-term Borrowings
The Missouri Credit Agreement and the Illinois Credit Agreement are available to support issuances under Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper programs, respectively, subject to borrowing sublimits, and the issuance of letters of credit. As of September 30, 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 $1.1 billion. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of September 30, 2024. As of September 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 September 30, 2024, and December 31, 2023. There were no borrowings outstanding under the Credit Agreements as of September 30, 2024, or December 31, 2023.

| September 30, 2024 |  |  | December 31, 2023
Ameren (parent) | $ | 946 |  |  |  | $ | — |
Ameren Missouri | 576 |  |  |  | 170 |
Ameren Illinois | 17 |  |  |  | 366 |
Ameren consolidated | $ | 1,539 |  |  |  | $ | 536 |

The following table summarizes the activity and relevant interest rates for Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper issuances under the Credit Agreements for the nine months ended September 30, 2024 and 2023:

|  | Ameren (parent) |  | Ameren Missouri |  | Ameren Illinois |  | Ameren Consolidated |
2024 |  |  |  |  |  |  |  |  |
Average daily amount outstanding |  | $ | 177 |  |  | $ | 187 |  |  | $ | 256 |  |  | $ | 620 |  |
Weighted-average interest rate |  | 5.46 | % |  | 5.52 | % |  | 5.57 | % |  | 5.53 | % |
Peak amount outstanding during period(a) |  | $ | 948 |  |  | $ | 576 |  |  | $ | 694 |  |  | $ | 1,542 |  |
Peak interest rate |  | 5.60 | % |  | 5.68 | % |  | 5.68 | % |  | 5.68 | % |
2023 |  |  |  |  |  |  |  |  |
Average daily amount outstanding |  | $ | 687 |  |  | $ | 306 |  |  | $ | 181 |  |  | $ | 1,174 |  |
Weighted-average interest rate |  | 5.29 | % |  | 5.15 | % |  | 5.15 | % |  | 5.24 | % |
Peak amount outstanding during period(a) |  | $ | 1,127 |  |  | $ | 592 |  |  | $ | 450 |  |  | $ | 1,381 |  |
Peak interest rate |  | 5.60 | % |  | 5.60 | % |  | 5.60 | % |  | 5.60 | % |

(a)The timing of peak outstanding commercial paper issuances 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 nine months ended September 30, 2024, was 5.29% and 5.37%, respectively (2023 – 5.50% and 5.20%, 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 nine months ended September 30, 2024 and 2023.
NOTE 4 – LONG-TERM DEBT AND EQUITY FINANCINGS
Ameren
For the three and nine months ended September 30, 2024, Ameren issued a total of 0.1 million and 0.4 million shares of common stock, under its DRPlus and 401(k) plan, and received proceeds of $2 million and $23 million, respectively. As of September 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 nine months ended September 30, 2024. As of September 30, 2024, Ameren had approximately $615 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of September 30, 2024, discussed below.
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The forward sale agreements outstanding as of September 30, 2024, can be settled at Ameren’s discretion on or prior to dates ranging from January 14, 2025 to February 10, 2026. 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 $80.96. Each initial forward sale price is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75 basis points, and will be subject to decrease on certain dates specified in the forward sale agreements by specified amounts related to expected dividends on shares of the common stock during the term of the forward sale agreements. If the overnight bank funding rate is less than the spread on any day, the interest rate factor will result in a reduction of the forward sale price. The forward sale agreements will be physically settled unless Ameren elects to settle in cash or to net share settle. At September 30, 2024, Ameren could have settled the forward sale agreements with physical delivery of 4.7 million shares of common stock to the respective counterparties in exchange for cash of $386 million. Alternatively, the forward sale agreements could have also been settled at September 30, 2024, with delivery of approximately $29 million of cash or approximately 0.3 million shares of common stock to the counterparties. In connection with the forward sale agreements outstanding at September 30, 2024, the various counterparties, or their affiliates, borrowed from third parties and sold 4.7 million shares of common stock. The gross sales price of these shares totaled $388 million. Ameren has not received any proceeds from such sales of borrowed shares. The forward sale agreements have been classified as equity transactions.
In September 2024, $450 million principal amount of Ameren (parent)’s 2.50% senior unsecured notes matured and was repaid with commercial paper borrowings.
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 was repaid with cash on hand.
In October 2024, Ameren Missouri issued $450 million of 5.125% first mortgage bonds due March 2055, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2025. Net proceeds from this issuance were used for capital expenditures and to repay short-term debt.
Ameren Missouri received capital contributions totaling $350 million from Ameren (parent) during the nine months ended September 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.
ATXI
In August 2024, ATXI issued $70 million of 5.17% senior unsecured notes due September 2039 and $70 million of 5.42% senior unsecured notes due September 2053, pursuant to an August 2024 note purchase agreement. Both series of senior unsecured notes have interest payable semiannually on March 1 and September 1 of each year, beginning March 1, 2025, and were issued through a private placement offering exempt from registration under the Securities Act of 1933, as amended. Net proceeds from these issuances were used to repay a $49 million principal payment of ATXI’s 3.43% senior unsecured notes at maturity and 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 September 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.
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Off-balance-sheet Arrangements
At September 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.
NOTE 5 – OTHER INCOME, NET
The following table presents the components of “Other Income, Net” in the Ameren Companies’ statements of income for the three and nine months ended September 30, 2024 and 2023:

| Three Months |  | Nine Months |
| 2024 |  | 2023 |  | 2024 |  | 2023 |
Ameren: |  |  |  |  |  |  |  |
Allowance for equity funds used during construction | $ | 23 |  |  | $ | 16 |  |  | $ | 48 |  |  | $ | 39 |  |
Interest income on industrial development revenue bonds | — |  |  | — |  |  | — |  |  | 1 |  |
Other interest income | 8 |  |  | 6 |  |  | 29 |  |  | 23 |  |
Non-service cost components of net periodic benefit income(a) | 76 |  |  | 84 |  |  | 228 |  |  | 211 |  |
Miscellaneous income | — |  |  | 1 |  |  | 6 |  |  | 4 |  |
Earnings (losses) related to equity method investments | (2) |  |  | — |  |  | (1) |  |  | 2 |  |
Donations | (1) |  |  | (1) |  |  | (5) |  |  | (5) |  |
Miscellaneous expense | (3) |  |  | (5) |  |  | (12) |  |  | (14) |  |
Total Other Income, Net | $ | 101 |  |  | $ | 101 |  |  | $ | 293 |  |  | $ | 261 |  |
Ameren Missouri: |  |  |  |  |  |  |  |
Allowance for equity funds used during construction | $ | 15 |  |  | $ | 8 |  |  | $ | 38 |  |  | $ | 20 |  |
Interest income on industrial development revenue bonds | — |  |  | — |  |  | — |  |  | 1 |  |
Other interest income | 2 |  |  | 3 |  |  | 7 |  |  | 8 |  |
Non-service cost components of net periodic benefit income(a) | 35 |  |  | 34 |  |  | 104 |  |  | 62 |  |
Miscellaneous income | 1 |  |  | 1 |  |  | 3 |  |  | 3 |  |
Donations | — |  |  | — |  |  | (2) |  |  | (2) |  |
Miscellaneous expense | (2) |  |  | (2) |  |  | (6) |  |  | (7) |  |
Total Other Income, Net | $ | 51 |  |  | $ | 44 |  |  | $ | 144 |  |  | $ | 85 |  |
Ameren Illinois: |  |  |  |  |  |  |  |
Allowance for equity funds used during construction | $ | 8 |  |  | $ | 5 |  |  | $ | 10 |  |  | $ | 15 |  |
Other interest income | 7 |  |  | 4 |  |  | 22 |  |  | 14 |  |
Non-service cost components of net periodic benefit income | 25 |  |  | 31 |  |  | 78 |  |  | 93 |  |
Miscellaneous income | — |  |  | — |  |  | 3 |  |  | 2 |  |
Donations | — |  |  | (1) |  |  | (2) |  |  | (3) |  |
Miscellaneous expense | (3) |  |  | (2) |  |  | (6) |  |  | (6) |  |
Total Other Income, Net | $ | 37 |  |  | $ | 37 |  |  | $ | 105 |  |  | $ | 115 |  |

(a)For the three and nine months ended September 30, 2024, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $(11) million and $(31) 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 $(2) million and $32 million, respectively, for the three and nine months ended September 30, 2023. See Note 11 – Retirement Benefits for additional information.
NOTE 6 – DERIVATIVE FINANCIAL INSTRUMENTS
We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following:
•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.
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The derivatives that we use to hedge these risks are governed by our risk management policies for forward contracts, futures, options, and swaps. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. The goal of the hedging program is generally to mitigate financial risks while ensuring that sufficient volumes are available to meet our requirements. Contracts we enter into as part of our risk management program may be settled financially, settled by physical delivery, or net settled with the counterparty.
All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. Many of our physical contracts, such as our purchased power contracts, qualify for the NPNS exception to derivative accounting rules. The revenue or expense on NPNS contracts is recognized at the contract price upon physical delivery. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting.
If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether the resulting gains or losses qualify for regulatory deferral. Derivative contracts that qualify for regulatory deferral are recorded at fair value, with changes in fair value recorded as regulatory assets or liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and liabilities are probable of recovery, or refund, through future rates charged to customers. Regulatory assets and liabilities are amortized to operating income as related losses and gains are reflected in rates charged to customers. Therefore, gains and losses on these derivatives have no effect on operating income. As of September 30, 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 September 30, 2024, and December 31, 2023. As of September 30, 2024, these contracts extended through October 2028, October 2029 and May 2032 for fuel oils, natural gas and power, respectively.

| Quantity (in millions, except as indicated)
| September 30, 2024 | December 31, 2023
Commodity | Ameren Missouri | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois | Ameren
Fuel oils (in gallons) | 25 |  | — |  | 25 |  | 17 |  | — |  | 17 |
Natural gas (in mmbtu) | 49 |  | 204 |  | 253 |  | 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 September 30, 2024, and December 31, 2023:

|  |  | September 30, 2024 | December 31, 2023
| Balance Sheet Location |  | Ameren Missouri |  |  | Ameren Illinois |  |  | Ameren |  |  |  | Ameren Missouri |  |  | Ameren Illinois |  |  | Ameren
Fuel oils | Other current assets |  | $ | — |  |  |  | $ | — |  |  |  | $ | — |  |  |  |  | $ | 2 |  |  |  | $ | — |  |  |  | $ | 2 |
Natural gas | Other current assets |  | 1 |  |  |  | 2 |  |  |  | 3 |  |  |  |  | — |  |  |  | — |  |  |  | — |
| Other assets |  | 2 |  |  |  | 1 |  |  |  | 3 |  |  |  |  | 3 |  |  |  | 3 |  |  |  | 6 |
Power | Other current assets |  | 10 |  |  |  | — |  |  |  | 10 |  |  |  |  | 5 |  |  |  | — |  |  |  | 5 |
Uranium | Other current assets |  | — |  |  |  | — |  |  |  | — |  |  |  |  | 9 |  |  |  | — |  |  |  | 9 |
| Total assets |  | $ | 13 |  |  |  | $ | 3 |  |  |  | $ | 16 |  |  |  |  | $ | 19 |  |  |  | $ | 3 |  |  |  | $ | 22 |
Fuel oils | Other current liabilities |  | $ | 3 |  |  |  | $ | — |  |  |  | $ | 3 |  |  |  |  | $ | 1 |  |  |  | $ | — |  |  |  | $ | 1 |
| Other deferred credits and liabilities |  | 2 |  |  |  | — |  |  |  | 2 |  |  |  |  | 1 |  |  |  | — |  |  |  | 1 |
Natural gas | Other current liabilities |  | 7 |  |  |  | 28 |  |  |  | 35 |  |  |  |  | 12 |  |  |  | 45 |  |  |  | 57 |
| Other deferred credits and liabilities |  | 9 |  |  |  | 29 |  |  |  | 38 |  |  |  |  | 10 |  |  |  | 30 |  |  |  | 40 |
Power | Other current liabilities |  | — |  |  |  | 11 |  |  |  | 11 |  |  |  |  | 1 |  |  |  | 12 |  |  |  | 13 |
| Other deferred credits and liabilities |  | — |  |  |  | 67 |  |  |  | 67 |  |  |  |  | — |  |  |  | 56 |  |  |  | 56 |
| Total liabilities |  | $ | 21 |  |  |  | $ | 135 |  |  |  | $ | 156 |  |  |  |  | $ | 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.
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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 September 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
September 30, 2024 |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |
Ameren Missouri |  | $ | 13 |  |  | $ | 3 |  |  | $ | — |  |  | $ | 10 |
Ameren Illinois |  | 3 |  |  | 2 |  |  | — |  |  | 1 |
Ameren |  | $ | 16 |  |  | $ | 5 |  |  | $ | — |  |  | $ | 11 |
Liabilities: |  |  |  |  |  |  |  |
Ameren Missouri |  | $ | 21 |  |  | $ | 3 |  |  | $ | — |  |  | $ | 18 |
Ameren Illinois |  | 135 |  |  | 2 |  |  | — |  |  | 133 |
Ameren |  | $ | 156 |  |  | $ | 5 |  |  | $ | — |  |  | $ | 151 |
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 September 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 September 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 Collateral Posted |  | Potential Aggregate Amount of Additional Collateral Required(b)
Ameren Missouri | $ | 21 |  |  | $ | — |  |  | $ | 18 |
Ameren Illinois | 57 |  |  | — |  |  | 55 |
Ameren | $ | 78 |  |  | $ | — |  |  | $ | 73 |

(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.
NOTE 7 – 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.
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We consider nonperformance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g., collateral). Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in the three and nine months ended September 30, 2024 or 2023. At September 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 September 30, 2024, and December 31, 2023:

|  | September 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 | $ | — |  | $ | — |  | $ | — |  | $ | — |  |  |  | $ | 2 |  | $ | — |  | $ | — |  | $ | 2 |  |
| Natural gas | — |  | 3 |  | — |  | 3 |  |  |  | — |  | 3 |  | — |  | 3 |  |
| Power | — |  | — |  | 10 |  | 10 |  |  |  | — |  | — |  | 5 |  | 5 |  |
| Uranium | — |  | — |  | — |  | — |  |  |  | — |  | — |  | 9 |  | 9 |  |
| Total derivative assets – commodity contracts | $ | — |  | $ | 3 |  | $ | 10 |  | $ | 13 |  |  |  | $ | 2 |  | $ | 3 |  | $ | 14 |  | $ | 19 |  |
| Nuclear decommissioning trust fund: |  |  |  |  |  |  |  |  |  |  |
| Equity securities: |  |  |  |  |  |  |  |  |  |  |
| U.S. large capitalization | $ | 888 |  | $ | — |  | $ | — |  | $ | 888 |  |  |  | $ | 787 |  | $ | — |  | $ | — |  | $ | 787 |  |
| Debt securities: |  |  |  |  |  |  |  |  |  |  |
| U.S. Treasury and agency securities | — |  | 212 |  | — |  | 212 |  |  |  | — |  | 150 |  | — |  | 150 |  |
| Corporate bonds | — |  | 147 |  | — |  | 147 |  |  |  | — |  | 136 |  | — |  | 136 |  |
| Other | — |  | 78 |  | — |  | 78 |  |  |  | — |  | 68 |  | — |  | 68 |  |
| Total nuclear decommissioning trust fund | $ | 888 |  | $ | 437 |  | $ | — |  | $ | 1,325 |  | (a) |  | $ | 787 |  | $ | 354 |  | $ | — |  | $ | 1,141 |  | (a)
| Total Ameren Missouri | $ | 888 |  | $ | 440 |  | $ | 10 |  | $ | 1,338 |  |  |  | $ | 789 |  | $ | 357 |  | $ | 14 |  | $ | 1,160 |  |
Ameren Illinois |  |  |  |  |  |  |  |  |  |  |
| Derivative assets – commodity contracts: |  |  |  |  |  |  |  |  |  |  |
| Natural gas | $ | 1 |  | $ | 1 |  | $ | 1 |  | $ | 3 |  |  |  | $ | — |  | $ | 1 |  | $ | 2 |  | $ | 3 |  |
| Total Ameren Illinois | $ | 1 |  | $ | 1 |  | $ | 1 |  | $ | 3 |  |  |  | $ | — |  | $ | 1 |  | $ | 2 |  | $ | 3 |  |
Ameren |  |  |  |  |  |  |  |  |  |  |
| Derivative assets – commodity contracts(b) | $ | 1 |  | $ | 4 |  | $ | 11 |  | $ | 16 |  |  |  | $ | 2 |  | $ | 4 |  | $ | 16 |  | $ | 22 |  |
| Nuclear decommissioning trust fund(c) | 888 |  | 437 |  | — |  | 1,325 |  | (a) |  | 787 |  | 354 |  | — |  | 1,141 |  | (a)
| Total Ameren | $ | 889 |  | $ | 441 |  | $ | 11 |  | $ | 1,341 |  |  |  | $ | 789 |  | $ | 358 |  | $ | 16 |  | $ | 1,163 |  |
Liabilities: |  |  |  |  |  |  |  |  |  |  |
Ameren Missouri |  |  |  |  |  |  |  |  |  |  |
| Derivative liabilities – commodity contracts: |  |  |  |  |  |  |  |  |  |  |
| Fuel oils | $ | 4 |  | $ | — |  | $ | 1 |  | $ | 5 |  |  |  | $ | 2 |  | $ | — |  | $ | — |  | $ | 2 |  |
| Natural gas | — |  | 15 |  | 1 |  | 16 |  |  |  | — |  | 19 |  | 3 |  | 22 |  |
| Power | — |  | — |  | — |  | — |  |  |  | — |  | — |  | 1 |  | 1 |  |
| Total Ameren Missouri | $ | 4 |  | $ | 15 |  | $ | 2 |  | $ | 21 |  |  |  | $ | 2 |  | $ | 19 |  | $ | 4 |  | $ | 25 |  |
Ameren Illinois |  |  |  |  |  |  |  |  |  |  |
| Derivative liabilities – commodity contracts: |  |  |  |  |  |  |  |  |  |  |
| Natural gas | $ | 3 |  | $ | 48 |  | $ | 6 |  | $ | 57 |  |  |  | $ | 4 |  | $ | 60 |  | $ | 11 |  | $ | 75 |  |
| Power | — |  | — |  | 78 |  | 78 |  |  |  | — |  | — |  | 68 |  | 68 |  |
| Total Ameren Illinois | $ | 3 |  | $ | 48 |  | $ | 84 |  | $ | 135 |  |  |  | $ | 4 |  | $ | 60 |  | $ | 79 |  | $ | 143 |  |
Ameren |  |  |  |  |  |  |  |  |  |  |
| Derivative liabilities – commodity contracts(b) | $ | 7 |  | $ | 63 |  | $ | 86 |  | $ | 156 |  |  |  | $ | 6 |  | $ | 79 |  | $ | 83 |  | $ | 168 |  |

(a)Balance excludes $8 million and $9 million of cash and cash equivalents, receivables, payables, and accrued income, net, for September 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.
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Level 3 fuel oils, natural gas, and uranium derivative contract assets and liabilities measured at fair value on a recurring basis were immaterial for all periods presented. The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and nine months ended September 30, 2024 and 2023:

| 2024 |  |  | 2023
| Ameren Missouri | Ameren Illinois |  |  | Ameren |  |  | Ameren Missouri | Ameren Illinois | Ameren
For the three months ended September 30: |  |  |  |  |  |  |  |  |  |
Beginning balance at July 1 | $ | 14 |  | $ | (61) |  |  |  | $ | (47) |  |  |  | $ | 14 |  | $ | (68) |  | $ | (54) |
Realized and unrealized gains/(losses) included in regulatory assets/liabilities | (1) |  | (21) |  |  |  | (22) |  |  |  | (5) |  | 1 |  | (4) |
Settlements | (3) |  | 4 |  |  |  | 1 |  |  |  | (3) |  | 3 |  | — |
Ending balance at September 30 | $ | 10 |  | $ | (78) |  |  |  | $ | (68) |  |  |  | $ | 6 |  | $ | (64) |  | $ | (58) |
Change in unrealized gains/(losses) related to assets/liabilities held at September 30 | $ | (1) |  | $ | (19) |  |  |  | $ | (20) |  |  |  | $ | (5) |  | $ | 1 |  | $ | (4) |
For the nine months ended September 30: |  |  |  |  |  |  |  |  |  |
Beginning balance at January 1 | $ | 4 |  | $ | (68) |  |  |  | $ | (64) |  |  |  | $ | 12 |  | $ | (33) |  | $ | (21) |
Realized and unrealized gains/(losses) included in regulatory assets/liabilities | 13 |  | (23) |  |  |  | (10) |  |  |  | 3 |  | (40) |  | (37) |
Settlements | (7) |  | 13 |  |  |  | 6 |  |  |  | (9) |  | 9 |  | — |
Ending balance at September 30 | $ | 10 |  | $ | (78) |  |  |  | $ | (68) |  |  |  | $ | 6 |  | $ | (64) |  | $ | (58) |
Change in unrealized gains/(losses) related to assets/liabilities held at September 30 | $ | 10 |  | $ | (18) |  |  |  | $ | (8) |  |  |  | $ | 6 |  | $ | (31) |  | $ | (25) |

All gains or losses related to our Level 3 derivative commodity contracts are expected to be recovered or returned through customer rates; therefore, there is no impact to either net income or other comprehensive income resulting from changes in the fair value of these instruments.
The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of September 30, 2024, and December 31, 2023:

|  |  | Fair Value |  |  |  | Weighted Average(b) |
| Commodity |  | Assets |  | Liabilities | Valuation Technique(s) | Unobservable Input(a) | Range |
2024 | Power(c) | $ | 10 | $ | (78) | Discounted cash flow | Average forward peak and off-peak pricing – forwards/swaps ($/MWh) | 31 – 59 | 40 |
|  |  |  |  |  |  | Nodal basis ($/MWh) | (8) – 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 September 30, 2024, and December 31, 2023:

Long-Term Debt (Including Current Portion): | Carrying Amount(a) |  |  |  | Fair Value |  |
|  |  | Level 2 |  | Level 3 |  | Total
| September 30, 2024
Ameren | $ | 16,722 |  |  |  |  | $ | 15,303 |  |  | $ | 570 |  | (b) | $ | 15,873 |
Ameren Missouri | 6,830 |  |  |  |  | 6,409 |  |  | — |  |  | 6,409 |
Ameren Illinois | 5,852 |  |  |  |  | 5,560 |  |  | — |  |  | 5,560 |
| 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 $123 million, $53 million, and $52 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of September 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.
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NOTE 8 – 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 $19 million and $22 million, respectively, as of September 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 September 30, 2024, and December 31, 2023:

| September 30, 2024 |  |  | December 31, 2023
| Ameren Missouri | Ameren Illinois |  |  | Ameren Missouri | Ameren Illinois
Income taxes payable to parent(a) | $ | 20 | $ | 105 |  |  | $ | — | $ | 2
Income taxes receivable from parent(b) | — | — |  |  | 56 | 22

(a)Included in “Accounts payable – affiliates” on the balance sheet.
(b)Included in “Accounts receivable – affiliates” on the balance sheet.
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Effects of Related-party Transactions on the Statement of Income
The following table presents the impact on Ameren Missouri and Ameren Illinois of related-party transactions for the three and nine months ended September 30, 2024 and 2023:

|  |  |  | Three Months |  | Nine Months
Agreement | Income Statement Line Item |  |  | Ameren Missouri |  | Ameren Illinois |  | Ameren Missouri |  | Ameren Illinois
Ameren Missouri power supply | Operating Revenues | 2024 | $ | (b) | $ | (a) | $ | (b) | $ | (a)
agreements with Ameren Illinois |  | 2023 |  | 2 |  |  | (a) |  | 2 |  |  | (a)
Ameren Missouri and Ameren Illinois | Operating Revenues | 2024 | $ | 8 |  | $ | (b) | $ | 23 |  | $ | (b)
rent and facility services |  | 2023 |  | 7 |  |  | (b) |  | 25 |  |  | (b)
Ameren Missouri and Ameren Illinois miscellaneous | Operating Revenues | 2024 | $ | 1 |  | $ | (b) | $ | 2 |  | $ | 1 |
support services |  | 2023 |  | (b) |  | 2 |  |  | (b) |  | 2 |
Total Operating Revenues |  | 2024 | $ | 9 |  | $ | (b) | $ | 25 |  | $ | 1 |
|  | 2023 |  | 9 |  |  | 2 |  |  | 27 |  |  | 2 |
Ameren Illinois power supply | Purchased Power | 2024 | $ | (a) | $ | (b) | $ | (a) | $ | (b)
agreements with Ameren Missouri |  | 2023 |  | (a) |  | 2 |  |  | (a) |  | 2 |
Ameren Missouri and Ameren Illinois | Purchased Power | 2024 | $ | 3 |  | $ | 1 |  | $ | 7 |  | $ | 2 |
transmission services from ATXI |  | 2023 |  | (b) |  | 1 |  |  | 1 |  |  | 1 |
Total Purchased Power |  | 2024 | $ | 3 |  | $ | 1 |  | $ | 7 |  | $ | 2 |
|  | 2023 |  | (b) |  | 3 |  |  | 1 |  |  | 3 |
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 | $ | 41 |  | $ | 38 |  | $ | 122 |  | $ | 115 |
agreement |  | 2023 |  | 36 |  |  | 33 |  |  | 106 |  |  | 101 |
Total Other Operations and |  | 2024 | $ | 41 |  | $ | 38 |  | $ | 122 |  | $ | 115 |
Maintenance |  | 2023 |  | 36 |  |  | 33 |  |  | 106 |  |  | 103 |
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.
NOTE 9 – 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
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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. The extent and duration of future curtailments are 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, 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 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. Both the United States Court of Appeals for the Eighth Circuit and the United States Supreme Court have granted applications to stay the EPA’s imposition of the federal implementation plan until resolution of appellate court challenges. A decision on the Good Neighbor Rule by the United States Court of Appeals for the Eighth Circuit is expected in 2025. 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
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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 based on the emissions expected from 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. Compliance with the new rule could be required as early as 2030 for certain existing coal-fired power plants and 2032 for certain natural gas-fired power plants. 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 to determine the legal merits of the final rule. In October 2024, the United States Supreme Court denied motions for stay of the final rule. 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, as well as requiring the use of continuous emissions monitoring systems. Compliance with the revised rule is required by July 2027, with a possible one-year extension if certain conditions are met. Requests for a stay of the revised rule have been denied by the United States Court of Appeals for the District of Columbia Circuit and the United States Supreme Court. Arguments regarding the legal merits of the revised rule will be considered by the United States Court of Appeals for the District of Columbia Circuit. Ameren and Ameren Missouri are monitoring the legal challenges and 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. In September 2023, the district court granted Ameren Missouri’s request to modify the remedy order to allow the early retirement of the Rush Island Energy Center in lieu of installing a flue gas desulfurization system. Ameren Missouri retired the Rush Island Energy Center on October 15, 2024. The United States Department of Justice is seeking an order from the district court providing for additional mitigation relief related to prior emissions. In November 2024, Ameren Missouri and the United States Department of Justice reached an agreement in principle, which, if approved by the district court, would resolve all outstanding claims in this case and would require Ameren Missouri to fund a program to provide electric buses and charging stations to schools in the metro St. Louis area and a program to provide air purifiers to eligible Ameren Missouri electric residential customers. These programs are estimated to cost approximately $64 million. As of September 30, 2024, Ameren and Ameren Missouri each recorded liabilities of $40 million and $24 million in “Other current liabilities” and “Other deferred credits and liabilities”, respectively, on their consolidated balance sheets and recorded charges of $15 million and $44 million in “Other operations and maintenance” on their consolidated statements of income in the first and third quarters of 2024, respectively, related to the cost of these programs.
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.
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
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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 disposal units. Ameren and Ameren Missouri have AROs of $47 million associated with CCR storage facilities recorded on their respective balance sheets as of September 30, 2024. This amount includes an immaterial incremental ARO related to the 2024 CCR Rule, which may 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 September 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 $93 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.
NOTE 10 – 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.
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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 Renewal Date | Maximum Coverages |  | Maximum Assessments for Single Incidents |
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.
NOTE 11 – RETIREMENT BENEFITS
The following table presents the components of the net periodic benefit cost (income) incurred for Ameren’s pension and postretirement benefit plans for the three and nine months ended September 30, 2024 and 2023:

| Pension Benefits |  |  | Postretirement Benefits
| Three Months |  | Nine Months |  |  | Three Months |  | Nine Months
| 2024 |  | 2023 |  | 2024 |  | 2023 |  |  | 2024 |  | 2023 |  | 2024 |  | 2023
Service cost(a) | $ | 22 |  |  | $ | 10 |  |  | $ | 66 |  |  | $ | 56 |  |  |  | $ | 3 |  |  | $ | 3 |  |  | $ | 9 |  |  | $ | 9 |
Non-service cost components: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest cost | 56 |  |  | 55 |  |  | 167 |  |  | 166 |  |  |  | 11 |  |  | 11 |  |  | 33 |  |  | 34 |
Expected return on plan assets(b) | (82) |  |  | (84) |  |  | (246) |  |  | (251) |  |  |  | (23) |  |  | (22) |  |  | (69) |  |  | (68) |
Amortization of(b): |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Prior service benefit | — |  |  | — |  |  | — |  |  | — |  |  |  | (1) |  |  | (1) |  |  | (3) |  |  | (3) |
Actuarial (gain) | (17) |  |  | (29) |  |  | (50) |  |  | (86) |  |  |  | (9) |  |  | (12) |  |  | (29) |  |  | (35) |
Total non-service cost components(c) | $ | (43) |  |  | $ | (58) |  |  | $ | (129) |  |  | $ | (171) |  |  |  | $ | (22) |  |  | $ | (24) |  |  | $ | (68) |  |  | $ | (72) |
Net periodic benefit income(d) | $ | (21) |  |  | $ | (48) |  |  | $ | (63) |  |  | $ | (115) |  |  |  | $ | (19) |  |  | $ | (21) |  |  | $ | (59) |  |  | $ | (63) |

(a)Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income.
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(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 nine months ended September 30, 2024 and 2023:

| Pension Benefits |  |  | Postretirement Benefits
| Three Months |  | Nine Months |  |  | Three Months |  | Nine Months
| 2024 |  | 2023 |  | 2024 |  | 2023 |  |  | 2024 |  | 2023 |  | 2024 |  | 2023
Ameren Missouri(a) | $ | (11) |  |  | $ | (24) |  |  | $ | (33) |  |  | $ | (59) |  |  |  | $ | (6) |  |  | $ | (8) |  |  | $ | (20) |  |  | $ | (23) |
Ameren Illinois | (8) |  |  | (21) |  |  | (25) |  |  | (48) |  |  |  | (13) |  |  | (13) |  |  | (39) |  |  | (40) |
Other | (2) |  |  | (3) |  |  | (5) |  |  | (8) |  |  |  | — |  |  | — |  |  | — |  |  | — |
Ameren(a) | $ | (21) |  |  | $ | (48) |  |  | $ | (63) |  |  | $ | (115) |  |  |  | $ | (19) |  |  | $ | (21) |  |  | $ | (59) |  |  | $ | (63) |

(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.
NOTE 12 – INCOME TAXES
The following table presents a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the three and nine months ended September 30, 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) | (9) |  |  | (7) |  |  | (15) |  |  | (15) |  |  | (4) |  |  | (2) |  |
Amortization of deferred investment tax credit | — |  |  | — |  |  | — |  |  | (1) |  |  | — |  |  | — |  |
Renewable and other tax credits(b) | (4) |  |  | (5) |  |  | (10) |  |  | (11) |  |  | — |  |  | (1) |  |
State tax | 4 |  |  | 4 |  |  | 3 |  |  | 3 |  |  | 7 |  |  | 7 |  |
Depreciation differences | — |  |  | (1) |  |  | (1) |  |  | — |  |  | — |  |  | — |  |
Other permanent items | (1) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |
Effective income tax rate | 11 | % |  | 12 | % |  | (2) | % |  | (3) | % |  | 24 | % |  | 25 | % |
Nine 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) |  |
Amortization of deferred investment tax credit | — |  |  | — |  |  | — |  |  | (1) |  |  | — |  |  | — |  |
Renewable and other tax credits(b) | (5) |  |  | (5) |  |  | (10) |  |  | (11) |  |  | — |  |  | — |  |
State tax | 5 |  |  | 5 |  |  | 3 |  |  | 3 |  |  | 7 |  |  | 7 |  |
Depreciation differences | — |  |  | — |  |  | (1) |  |  | — |  |  | — |  |  | (1) |  |
Effective income tax rate | 13 | % |  | 13 | % |  | (1) | % |  | (3) | % |  | 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)The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM.
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NOTE 13 – SUPPLEMENTAL INFORMATION
Cash, Cash Equivalents, and Restricted Cash
The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets and the statements of cash flows at September 30, 2024, and December 31, 2023:

| September 30, 2024 |  |  | December 31, 2023
Ameren |  | Ameren Missouri |  | Ameren Illinois |  |  | Ameren |  | Ameren Missouri |  | Ameren Illinois
“Cash and cash equivalents” | $ | 17 |  |  | $ | — |  |  | $ | — |  |  |  | $ | 25 |  |  | $ | — |  |  | $ | — |
Restricted cash included in “Other current assets” | 15 |  |  | 5 |  |  | 6 |  |  |  | 13 |  |  | 5 |  |  | 5 |
Restricted cash included in “Other assets” | 287 |  |  | — |  |  | 287 |  |  |  | 229 |  |  | — |  |  | 229 |
Restricted cash included in “Nuclear decommissioning trust fund” | 5 |  |  | 5 |  |  | — |  |  |  | 5 |  |  | 5 |  |  | — |
Total cash, cash equivalents, and restricted cash | $ | 324 |  |  | $ | 10 |  |  | $ | 293 |  |  |  | $ | 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 September 30, 2024, and December 31, 2023, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of $53 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 nine months ended September 30, 2024 and 2023:

| Three Months |  | Nine Months
| 2024 |  | 2023 |  |  | 2024 |  | 2023 |
Ameren: |  |  |  |  |  |  |  |  |
Beginning of period | $ | 37 |  |  | $ | 39 |  |  |  | $ | 30 |  |  | $ | 31 |  |
Bad debt expense | 12 |  |  | 18 |  |  |  | 28 |  |  | 41 |  |
Charged to other accounts(a) | 2 |  |  | 2 |  |  |  | 6 |  |  | 3 |  |
Net write-offs | (20) |  |  | (26) |  |  |  | (33) |  |  | (42) |  |
End of period | $ | 31 |  |  | $ | 33 |  |  |  | $ | 31 |  |  | $ | 33 |  |
Ameren Missouri: |  |  |  |  |  |  |  |  |
Beginning of period | $ | 12 |  |  | $ | 12 |  |  |  | $ | 12 |  |  | $ | 13 |  |
Bad debt expense | 3 |  |  | 5 |  |  |  | 8 |  |  | 9 |  |
Net write-offs | (3) |  |  | (5) |  |  |  | (8) |  |  | (10) |  |
End of period | $ | 12 |  |  | $ | 12 |  |  |  | $ | 12 |  |  | $ | 12 |  |
Ameren Illinois:(b) |  |  |  |  |  |  |  |  |
Beginning of period | $ | 25 |  |  | $ | 27 |  |  |  | $ | 18 |  |  | $ | 18 |  |
Bad debt expense | 9 |  |  | 13 |  |  |  | 20 |  |  | 32 |  |
Charged to other accounts(a) | 2 |  |  | 2 |  |  |  | 6 |  |  | 3 |  |
Net write-offs | (17) |  |  | (21) |  |  |  | (25) |  |  | (32) |  |
End of period | $ | 19 |  |  | $ | 21 |  |  |  | $ | 19 |  |  | $ | 21 |  |

(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.
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Leases
Ameren and Ameren Missouri primarily lease rail cars and land related to solar generation facilities under operating lease arrangements. The land leases are related to the acquisitions of the Cass County Solar Project and Boomtown Solar Project. See Note 2 – Rate and Regulatory Matters for additional information on the acquisitions. Rail cars are leased for the transportation of coal to its energy centers. For rail car leases, we account for the lease and non-lease components as a single lease component, and for the land leases related to solar generation projects, we account for the components separately for each agreement. Certain of the land leases related to the acquisitions of the Cass County Solar Project and Boomtown Solar Project have options to extend or terminate those leases. Renewal options are not expected to be exercised and are not included in any of the lease measurements used to record the leased assets and liabilities in the tables below. No termination options have been included in any of the lease measurements used to record the leased assets and liabilities in the tables below.
The following table provides supplemental balance sheet information related to operating leases as of September 30, 2024:

| Ameren |  | Ameren Missouri |  |
Other assets | $ | 38 |  |  | $ | 35 |  |  |
Other current liabilities | 6 |  |  | 5 |  |  |
Other deferred credits and liabilities | 32 |  |  | 30 |  |  |
Weighted average remaining operating lease term | 23 years |  | 24 years |  |
Weighted average discount rate(a) | 5.4 | % |  | 5.4 | % |  |

(a)As an implicit rate is not readily determinable under most of our lease agreements, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. We use an implicit rate when readily determinable.
The following table presents Ameren’s and Ameren Missouri’s remaining maturities of operating lease liabilities as of September 30, 2024:

| Ameren |  | Ameren Missouri
2024 | $ | 2 |  |  | $ | 2 |
2025 | 6 |  |  | 5 |
2026 | 3 |  |  | 2 |
2027 | 2 |  |  | 2 |
2028 | 2 |  |  | 2 |
Thereafter | 55 |  |  | 53 |
Total lease payments | $ | 70 |  |  | $ | 66 |
Less imputed interest | 32 |  |  | 31 |
Total | $ | 38 |  |  | $ | 35 |

Supplemental Cash Flow Information
The following table provides noncash financing and investing activity excluded from the statements of cash flows for the nine months ended September 30, 2024 and 2023:

| September 30, 2024 |  | September 30, 2023
Ameren | Ameren Missouri |  | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois
Investing: |  |  |  |  |  |  |  |
Accrued capital expenditures, including nuclear fuel expenditures | $ | 404 |  | $ | 257 |  |  | $ | 127 |  |  | $ | 518 |  | $ | 246 |  | $ | 237 |
Net realized and unrealized gain – nuclear decommissioning trust fund | 163 |  | 163 |  |  | — |  |  | 66 |  | 66 |  | — |
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.
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Asset Retirement Obligations
The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the nine months ended September 30, 2024:

| Ameren Missouri |  | Ameren Illinois |  |  |  | Ameren |
Balance at December 31, 2023 | $ | 787 |  | (a) | $ | 4 |  |  |  | (b) | $ | 791 |  | (a)
Liabilities incurred | 17 |  | (c) | — |  |  |  |  | 17 |  | (c)
Liabilities settled | (9) |  |  | (1) |  |  |  |  | (10) |  |
Accretion | 26 |  | (d) | — |  |  |  |  | 26 |  | (d)
Change in estimates | (7) |  |  | — |  |  |  |  | (7) |  |
Balance at September 30, 2024 | $ | 814 |  | (a) | $ | 3 |  |  |  | (b) | $ | 817 |  | (a)

(a)Balance included $19 million in “Other current liabilities” on the balance sheet as of both September 30, 2024, and December 31, 2023.
(b)Included in “Other deferred credits and liabilities” on the balance sheet.
(c)In June and September 2024, Ameren and Ameren Missouri recorded an ARO related to the decommissioning for the Cass County Solar Project and the Boomtown Solar Project, respectively. In addition, as a result of the 2024 CCR Rule, Ameren and Ameren Missouri recorded an 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 nine months ended September 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 September 30, 2024, and December 31, 2023, the present value of benefits to be paid for deferred compensation obligations was $81 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 September 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 nine months ended September 30, 2024 and 2023:

| Three Months |  | Nine Months
| 2024 |  | 2023 |  | 2024 |  | 2023
Ameren Missouri | $ | 60 |  |  | $ | 60 |  |  | $ | 136 |  |  | $ | 133 |
Ameren Illinois | 29 |  |  | 27 |  |  | 94 |  |  | 90 |
Ameren | $ | 89 |  |  | $ | 87 |  |  | $ | 230 |  |  | $ | 223 |

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Earnings per Share
The following table reconciles the basic weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding for the three and nine months ended September 30, 2024 and 2023:

| Three Months |  | Nine Months
| 2024 |  | 2023 |  | 2024 |  | 2023
Weighted-average Common Shares Outstanding – Basic | 266.8 |  |  | 262.8 |  |  | 266.6 |  |  | 262.5 |
Assumed settlement of performance share units and restricted stock units | 0.4 |  |  | 0.6 |  |  | 0.3 |  |  | 0.7 |
Dilutive effect of forward sale agreements | 0.1 |  |  | — |  |  | — |  |  | — |
Weighted-average Common Shares Outstanding – Diluted(a) | 267.3 |  |  | 263.4 |  |  | 266.9 |  |  | 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 nine months ended September 30, 2024 and 2023. Outstanding forward sale agreements as of September 30, 2024 that were anti-dilutive for the three and nine months ended September 30, 2024 were excluded from the earnings per diluted share calculation as calculated using the treasury stock method. The outstanding forward sale agreements as of September 30, 2023 were anti-dilutive for the three and nine months ended September 30, 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.
NOTE 14 – SEGMENT INFORMATION
The following tables present revenues, net income attributable to common shareholders, and capital expenditures by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 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 | $ | 1,333 |  |  | $ | 551 |  |  | $ | 121 |  |  | $ | 168 |  |  | $ | — |  |  | $ | — |  |  | $ | 2,173 |  |
Intersegment revenues | 9 |  |  | 1 |  |  | — |  |  | 42 |  |  | — |  |  | (52) |  |  | — |  |
Net income (loss) attributable to Ameren common shareholders | 381 |  |  | 56 |  |  | (10) |  |  | 90 |  | (a) | (61) |  |  | — |  |  | 456 |  |
Capital expenditures | 735 |  |  | 152 |  |  | 83 |  |  | 174 |  |  | 2 |  |  | (9) |  |  | 1,137 |  |
Three Months 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |
External revenues | $ | 1,228 |  |  | $ | 557 |  |  | $ | 121 |  |  | $ | 154 |  |  | $ | — |  |  | $ | — |  |  | $ | 2,060 |  |
Intersegment revenues | 9 |  |  | 1 |  |  | 1 |  |  | 34 |  |  | — |  |  | (45) |  |  | — |  |
Net income (loss) attributable to Ameren common shareholders | 411 |  |  | 66 |  |  | (5) |  |  | 86 |  | (a) | (65) |  |  | — |  |  | 493 |  |
Capital expenditures | 341 |  |  | 177 |  |  | 80 |  |  | 160 |  |  | 2 |  |  | (11) |  |  | 749 |  |
Nine Months 2024: |  |  |  |  |  |  |  |  |  |  |  |  |  |
External revenues | $ | 2,980 |  |  | $ | 1,566 |  |  | $ | 660 |  |  | $ | 476 |  |  | $ | — |  |  | $ | — |  |  | $ | 5,682 |  |
Intersegment revenues | 25 |  |  | 1 |  |  | — |  |  | 110 |  |  | — |  |  | (136) |  |  | — |  |
Net income (loss) attributable to Ameren common shareholders | 534 |  |  | 173 |  |  | 102 |  |  | 241 |  | (a) | (75) |  |  | — |  |  | 975 |  |
Capital expenditures | 1,839 |  |  | 468 |  |  | 202 |  |  | 515 |  |  | 6 |  |  | (1) |  |  | 3,029 |  |
Nine Months 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |
External revenues | $ | 3,074 |  |  | $ | 1,721 |  |  | $ | 664 |  |  | $ | 423 |  |  | $ | — |  |  | $ | — |  |  | $ | 5,882 |  |
Intersegment revenues | 27 |  |  | 1 |  |  | 1 |  |  | 89 |  |  | — |  |  | (118) |  |  | — |  |
Net income (loss) attributable to Ameren common shareholders | 541 |  |  | 193 |  |  | 93 |  |  | 229 |  | (a) | (62) |  |  | — |  |  | 994 |  |
Capital expenditures | 1,255 |  |  | 527 |  |  | 221 |  |  | 570 |  |  | 7 |  |  | (9) |  |  | 2,571 |  |

(a)Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent).
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Ameren Illinois

| Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Illinois Transmission |  | Intersegment Eliminations |  | Ameren Illinois
Three Months 2024: |  |  |  |  |  |  |  |  |
External revenues | $ | 552 |  |  | $ | 121 |  |  | $ | 120 |  |  | $ | — |  |  | $ | 793 |
Intersegment revenues | — |  |  | — |  |  | 35 |  |  | (35) |  |  | — |
Net income (loss) available to common shareholder | 56 |  |  | (10) |  |  | 68 |  |  | — |  |  | 114 |
Capital expenditures | 152 |  |  | 83 |  |  | 139 |  |  | — |  |  | 374 |
Three Months 2023: |  |  |  |  |  |  |  |  |
External revenues | $ | 558 |  |  | $ | 122 |  |  | $ | 103 |  |  | $ | — |  |  | $ | 783 |
Intersegment revenues | — |  |  | — |  |  | 33 |  |  | (33) |  |  | — |
Net income (loss) available to common shareholder | 66 |  |  | (5) |  |  | 64 |  |  | — |  |  | 125 |
Capital expenditures | 177 |  |  | 80 |  |  | 125 |  |  | — |  |  | 382 |
Nine Months 2024: |  |  |  |  |  |  |  |  |
External revenues | $ | 1,567 |  |  | $ | 660 |  |  | $ | 332 |  |  | $ | — |  |  | $ | 2,559 |
Intersegment revenues | — |  |  | — |  |  | 90 |  |  | (90) |  |  | — |
Net income available to common shareholder | 173 |  |  | 102 |  |  | 178 |  |  | — |  |  | 453 |
Capital expenditures | 468 |  |  | 202 |  |  | 421 |  |  | — |  |  | 1,091 |
Nine Months 2023: |  |  |  |  |  |  |  |  |
External revenues | $ | 1,722 |  |  | $ | 665 |  |  | $ | 276 |  |  | $ | — |  |  | $ | 2,663 |
Intersegment revenues | — |  |  | — |  |  | 87 |  |  | (87) |  |  | — |
Net income available to common shareholder | 193 |  |  | 93 |  |  | 166 |  |  | — |  |  | 452 |
Capital expenditures | 527 |  |  | 221 |  |  | 478 |  |  | — |  |  | 1,226 |

The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and nine months ended September 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 | $ | 590 |  |  | $ | 339 |  |  | $ | — |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 929 |  |
Commercial | 465 |  |  | 184 |  |  | — |  |  | — |  |  |  |  | — |  |  | 649 |  |
Industrial | 108 |  |  | 38 |  |  | — |  |  | — |  |  |  |  | — |  |  | 146 |  |
Other | 161 |  |  | (9) |  | (a) | — |  |  | 210 |  |  |  |  | (51) |  |  | 311 |  |
Total electric revenues | $ | 1,324 |  |  | $ | 552 |  |  | $ | — |  |  | $ | 210 |  |  |  |  | $ | (51) |  |  | $ | 2,035 |  |
Residential | $ | 9 |  |  | $ | — |  |  | $ | 77 |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 86 |  |
Commercial | 5 |  |  | — |  |  | 19 |  |  | — |  |  |  |  | — |  |  | 24 |  |
Industrial | — |  |  | — |  |  | 2 |  |  | — |  |  |  |  | — |  |  | 2 |  |
Other | 4 |  |  | — |  |  | 23 |  |  | — |  |  |  |  | (1) |  |  | 26 |  |
Total natural gas revenues | $ | 18 |  |  | $ | — |  |  | $ | 121 |  |  | $ | — |  |  |  |  | $ | (1) |  |  | $ | 138 |  |
Total revenues(b) | $ | 1,342 |  |  | $ | 552 |  |  | $ | 121 |  |  | $ | 210 |  |  |  |  | $ | (52) |  |  | $ | 2,173 |  |

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| Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission |  |  |  | Intersegment Eliminations |  | Ameren |
Three Months 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 590 |  |  | $ | 330 |  |  | $ | — |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 920 |  |
Commercial | 468 |  |  | 189 |  |  | — |  |  | — |  |  |  |  | — |  |  | 657 |  |
Industrial | 107 |  |  | 40 |  |  | — |  |  | — |  |  |  |  | — |  |  | 147 |  |
Other | 54 |  |  | (1) |  | (a) | — |  |  | 188 |  |  |  |  | (44) |  |  | 197 |  |
Total electric revenues | $ | 1,219 |  |  | $ | 558 |  |  | $ | — |  |  | $ | 188 |  |  |  |  | $ | (44) |  |  | $ | 1,921 |  |
Residential | $ | 9 |  |  | $ | — |  |  | $ | 75 |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 84 |  |
Commercial | 5 |  |  | — |  |  | 19 |  |  | — |  |  |  |  | — |  |  | 24 |  |
Industrial | 1 |  |  | — |  |  | 1 |  |  | — |  |  |  |  | — |  |  | 2 |  |
Other | 3 |  |  | — |  |  | 27 |  |  | — |  |  |  |  | (1) |  |  | 29 |  |
Total natural gas revenues | $ | 18 |  |  | $ | — |  |  | $ | 122 |  |  | $ | — |  |  |  |  | $ | (1) |  |  | $ | 139 |  |
Total revenues(b) | $ | 1,237 |  |  | $ | 558 |  |  | $ | 122 |  |  | $ | 188 |  |  |  |  | $ | (45) |  |  | $ | 2,060 |  |
Nine Months 2024: |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,326 |  |  | $ | 947 |  |  | $ | — |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 2,273 |  |
Commercial | 1,048 |  |  | 512 |  |  | — |  |  | — |  |  |  |  | — |  |  | 1,560 |  |
Industrial | 246 |  |  | 130 |  |  | — |  |  | — |  |  |  |  | — |  |  | 376 |  |
Other | 282 |  |  | (22) |  | (a) | — |  |  | 586 |  |  |  |  | (135) |  |  | 711 |  |
Total electric revenues | $ | 2,902 |  |  | $ | 1,567 |  |  | $ | — |  |  | $ | 586 |  |  |  |  | $ | (135) |  |  | $ | 4,920 |  |
Residential | $ | 62 |  |  | $ | — |  |  | $ | 466 |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 528 |  |
Commercial | 26 |  |  | — |  |  | 111 |  |  | — |  |  |  |  | — |  |  | 137 |  |
Industrial | 3 |  |  | — |  |  | 7 |  |  | — |  |  |  |  | — |  |  | 10 |  |
Other | 12 |  |  | — |  |  | 76 |  |  | — |  |  |  |  | (1) |  |  | 87 |  |
Total natural gas revenues | $ | 103 |  |  | $ | — |  |  | $ | 660 |  |  | $ | — |  |  |  |  | $ | (1) |  |  | $ | 762 |  |
Total revenues(b) | $ | 3,005 |  |  | $ | 1,567 |  |  | $ | 660 |  |  | $ | 586 |  |  |  |  | $ | (136) |  |  | $ | 5,682 |  |
Nine Months 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,274 |  |  | $ | 1,049 |  |  | $ | — |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 2,323 |  |
Commercial | 1,026 |  |  | 582 |  |  | — |  |  | — |  |  |  |  | — |  |  | 1,608 |  |
Industrial | 243 |  |  | 136 |  |  | — |  |  | — |  |  |  |  | — |  |  | 379 |  |
Other | 435 |  |  | (45) |  | (a) | — |  |  | 512 |  |  |  |  | (116) |  |  | 786 |  |
Total electric revenues | $ | 2,978 |  |  | $ | 1,722 |  |  | $ | — |  |  | $ | 512 |  |  |  |  | $ | (116) |  |  | $ | 5,096 |  |
Residential | $ | 74 |  |  | $ | — |  |  | $ | 469 |  |  | $ | — |  |  |  |  | $ | — |  |  | $ | 543 |  |
Commercial | 34 |  |  | — |  |  | 121 |  |  | — |  |  |  |  | — |  |  | 155 |  |
Industrial | 4 |  |  | — |  |  | 10 |  |  | — |  |  |  |  | — |  |  | 14 |  |
Other | 11 |  |  | — |  |  | 65 |  |  | — |  |  |  |  | (2) |  |  | 74 |  |
Total natural gas revenues | $ | 123 |  |  | $ | — |  |  | $ | 665 |  |  | $ | — |  |  |  |  | $ | (2) |  |  | $ | 786 |  |
Total revenues(b) | $ | 3,101 |  |  | $ | 1,722 |  |  | $ | 665 |  |  | $ | 512 |  |  |  |  | $ | (118) |  |  | $ | 5,882 |  |

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(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 nine months ended September 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 | $ | — |  |  | $ | (144) |  |  | $ | (9) |  |  | $ | (2) |  |  | $ | (155) |  |
Other revenues not from contracts with customers | 2 |  |  | 2 |  |  | — |  |  | — |  |  | 4 |  |
Three Months 2023: |  |  |  |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | (9) |  |  | $ | (94) |  |  | $ | (1) |  |  | $ | (5) |  |  | $ | (109) |  |
Other revenues not from contracts with customers | (1) |  | (a) | 2 |  |  | — |  |  | — |  |  | 1 |  | (a)
Nine Months 2024: |  |  |  |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | (7) |  |  | $ | (83) |  |  | $ | 10 |  |  | $ | 11 |  |  | $ | (69) |  |
Other revenues not from contracts with customers | 4 |  |  | 5 |  |  | 2 |  |  | — |  |  | 11 |  |
Nine Months 2023: |  |  |  |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | (11) |  |  | $ | 30 |  |  | $ | 36 |  |  | $ | 8 |  |  | $ | 63 |  |
Other revenues not from contracts with customers | (9) |  | (a) | 6 |  |  | 2 |  |  | — |  |  | (1) |  | (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 | $ | 339 |  |  | $ | 77 |  |  | $ | — |  |  | $ | — |  |  | $ | 416 |  |
Commercial | 184 |  |  | 19 |  |  | — |  |  | — |  |  | 203 |  |
Industrial | 38 |  |  | 2 |  |  | — |  |  | — |  |  | 40 |  |
Other | (9) |  | (a) | 23 |  |  | 155 |  |  | (35) |  |  | 134 |  |
Total revenues(b) | $ | 552 |  |  | $ | 121 |  |  | $ | 155 |  |  | $ | (35) |  |  | $ | 793 |  |
Three Months 2023: |  |  |  |  |  |  |  |  |  |
Residential | $ | 330 |  |  | $ | 75 |  |  | $ | — |  |  | $ | — |  |  | $ | 405 |  |
Commercial | 189 |  |  | 19 |  |  | — |  |  | — |  |  | 208 |  |
Industrial | 40 |  |  | 1 |  |  | — |  |  | — |  |  | 41 |  |
Other | (1) |  | (a) | 27 |  |  | 136 |  |  | (33) |  |  | 129 |  |
Total revenues(b) | $ | 558 |  |  | $ | 122 |  |  | $ | 136 |  |  | $ | (33) |  |  | $ | 783 |  |
Nine Months 2024: |  |  |  |  |  |  |  |  |  |
Residential | $ | 947 |  |  | $ | 466 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,413 |  |
Commercial | 512 |  |  | 111 |  |  | — |  |  | — |  |  | 623 |  |
Industrial | 130 |  |  | 7 |  |  | — |  |  | — |  |  | 137 |  |
Other | (22) |  | (a) | 76 |  |  | 422 |  |  | (90) |  |  | 386 |  |
Total revenues(b) | $ | 1,567 |  |  | $ | 660 |  |  | $ | 422 |  |  | $ | (90) |  |  | $ | 2,559 |  |
Nine Months 2023: |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,049 |  |  | $ | 469 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,518 |  |
Commercial | 582 |  |  | 121 |  |  | — |  |  | — |  |  | 703 |  |
Industrial | 136 |  |  | 10 |  |  | — |  |  | — |  |  | 146 |  |
Other | (45) |  | (a) | 65 |  |  | 363 |  |  | (87) |  |  | 296 |  |
Total revenues(b) | $ | 1,722 |  |  | $ | 665 |  |  | $ | 363 |  |  | $ | (87) |  |  | $ | 2,663 |  |

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(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 nine months ended September 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 | $ | (144) |  |  | $ | (9) |  |  | $ | (1) |  |  | $ | (154) |
Other revenues not from contracts with customers | 2 |  |  | — |  |  | — |  |  | 2 |
Three Months 2023: |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | (94) |  |  | $ | (1) |  |  | $ | (6) |  |  | $ | (101) |
Other revenues not from contracts with customers | 2 |  |  | — |  |  | — |  |  | 2 |
Nine Months 2024: |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | (83) |  |  | $ | 10 |  |  | $ | 9 |  |  | $ | (64) |
Other revenues not from contracts with customers | 5 |  |  | 2 |  |  | — |  |  | 7 |
Nine Months 2023: |  |  |  |  |  |  |
Revenues from alternative revenue programs | $ | 30 |  |  | $ | 36 |  |  | $ | 4 |  |  | $ | 70 |
Other revenues not from contracts with customers | 6 |  |  | 2 |  |  | — |  |  | 8 |

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
The following discussion should be read in conjunction with the financial statements contained in this Form 10-Q, as well as Management’s Discussion and Analysis of Financial Condition and Results of Operations and Risk Factors contained in the Form 10-K. We intend for this discussion to provide the reader with information that will assist in understanding our financial statements, the changes in certain key items in those financial statements, and the primary factors that accounted for those changes, as well as how certain accounting principles affect our financial statements. The discussion also provides information about the financial results of our business segments to provide a better understanding of how those segments and their results affect the financial condition and results of operations of Ameren as a whole. Also see the Glossary of Terms and Abbreviations at the front of this report and in the Form 10-K.
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.
•Ameren Missouri operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri.
•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 within 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.
In addition to presenting results of operations and earnings amounts in total, we present certain information in cents per share. These amounts reflect factors that directly affect Ameren’s earnings. We believe this per share information helps readers to understand the impact of these factors on Ameren’s earnings per share.
OVERVIEW
Net income attributable to Ameren common shareholders in the three months ended September 30, 2024, was $456 million, or $1.70 per diluted share, compared with $493 million, or $1.87 per diluted share, in the year-ago period. Net income attributable to Ameren common shareholders in the nine months ended September 30, 2024, was $975 million, or $3.65 per diluted share, compared with $994 million, or $3.78 per diluted share, in the year-ago period. Earnings for the three and nine months ended September 30, 2024, were unfavorably affected by increased other operations and maintenance expenses not subject to formula rates, riders, or trackers, due to a charge recorded by Ameren Missouri related to an agreement in principle with the United States Department of Justice, which, if approved, would resolve all outstanding claims in the NSR and Clean Air Act litigation related to the Rush Island Energy Center. Earnings in the three and nine months ended September 30, 2024, were also unfavorably affected by increased financing costs due to higher long-term debt balances and interest rates, a lower recognized ROE under the MYRP, lower Ameren Transmission earnings resulting from the October 2024 FERC order lowering the allowed base ROE, and an increase in the weighted-average basic common shares outstanding, which reduced earnings per diluted
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share. Net income for the three and nine months ended September 30, 2024, was favorably affected by increased rate base investments at Ameren Transmission and increased deferral of financing costs associated with rate base investments at Ameren Missouri. Net income for the nine months ended September 30, 2024, was favorably affected by increased base rate revenues pursuant to the MoPSC's June 2023 electric rate order and increased retail electric sales volumes at Ameren Missouri. Earnings for the nine months ended September 30, 2024, were also favorably affected by higher base rate revenues pursuant to the ICC's November 2023 natural gas rate order, which increased earnings at Ameren Illinois Natural Gas. Net income for the three months ended September 30, 2024, was unfavorably affected by decreased retail electric sales volumes at Ameren Missouri, primarily due to milder summer temperatures in 2024. Earnings for the three months ended September 30, 2024, were favorably affected by decreased other operations and maintenance expenses not subject to formula rates, riders, or trackers, primarily at Ameren Missouri and Ameren Illinois Natural Gas, excluding a charge related to an increase in the cost of additional mitigation relief discussed above, largely due to lower storm costs, an increase in the cash surrender value of COLI, and disciplined cost management including lower labor costs from decreased headcount, decreased use of contractors, and lower amortization of refueling costs for the Callaway Energy Center.
Ameren’s strategic plan includes investing in rate-regulated energy infrastructure, enhancing regulatory frameworks and advocating for responsible policies, and optimizing operating performance to capitalize on opportunities to benefit our customers, communities, shareholders, and the environment. Ameren remains focused on disciplined cost management and strategic capital allocation. Ameren invested $3.0 billion in its rate-regulated businesses in the nine months ended September 30, 2024.
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% ROE, 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. 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.
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 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 under Part I, Item 1, of this report. 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 September 2024, the financing order became final and unappealable.
In September 2023, the United States District Court for the Eastern District of Missouri granted Ameren Missouri’s request to modify a September 2019 remedy order issued by the district court in 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. Ameren Missouri retired the Rush Island Energy Center on October 15, 2024. The United States Department of Justice is seeking an order from the district court providing for additional mitigation relief related to prior emissions. In November 2024, Ameren Missouri and the United States Department of Justice reached an agreement in principle, which, if approved by the district court, would resolve all outstanding claims in this case and would require Ameren Missouri to fund a program to provide electric buses and charging stations to schools in the metro St. Louis area and a program to provide air purifiers to eligible Ameren Missouri electric residential customers. These programs are estimated to cost approximately $64 million. As of September 30, 2024, Ameren and Ameren Missouri recorded liabilities of $64 million and charges of $15 million and $44 million in the first and third quarters of 2024, respectively, related to the cost of these programs.
In 2024, the MoPSC issued orders approving requested CCNs for the Split Rail, Vandalia, Bowling Green, and Cass County solar projects. Ameren Missouri acquired the Cass County, Boomtown, and Huck Finn solar projects in June 2024, September 2024, and October 2024, respectively. These three acquisitions collectively represent a purchase price of approximately $0.9 billion. In October 2024, the MoPSC issued an order approving a nonunanimous stipulation and agreement filed by Ameren Missouri, the MoPSC staff, and other intervenors requesting a CCN for the Castle Bluff Natural Gas Project. The order also includes the use of a post-construction cost deferral related to the project, which allows Ameren Missouri to defer and recover depreciation expense, financing costs, and applicable income taxes incurred from the date the project is placed in service to the date when project costs are reflected in updated base rates as a result of a regulatory rate review. The period of deferral would be limited to the earlier of the time the project costs are reflected in base rates or six months.
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In February 2024, Ameren Missouri filed an update to its Smart Energy Plan with the MoPSC, which includes a five-year capital investment overview with a detailed one-year plan for 2024. The plan is designed to upgrade Ameren Missouri’s electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $12.4 billion over the five-year period from 2024 through 2028, with expenditures largely recoverable under the PISA. Ameren Missouri’s Smart Energy Plan excludes investments in its natural gas distribution business, as well as removal costs, net of salvage.
In January 2024, Ameren Missouri filed a proposed customer energy-efficiency plan with the MoPSC under the MEEIA. In October 2024, Ameren Missouri, the MoOPC, and other intervenors filed a nonunanimous stipulation and agreement with the MoPSC for a three-year plan, which includes a portfolio of customer energy-efficiency and demand response 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 agreement is approved, Ameren Missouri intends to invest $51 million annually in 2025 and 2026 and $22 million in 2027 in the proposed customer energy-efficiency and demand response programs. In addition, the agreement requested performance incentives applicable to each plan year to earn revenues by achieving certain spending and demand response goals. If 100% of the goals are achieved in 2025, 2026, and 2027, Ameren Missouri would earn performance incentive revenues of $5 million, $5 million, and $2 million, respectively. Ameren Missouri expects a decision by the MoPSC in the fourth quarter of 2024, but cannot predict the ultimate outcome of this regulatory proceeding.
In September 2024, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for natural gas delivery service by $40 million. The natural gas rate increase request is based on a 10.25% ROE, a capital structure composed of 52% common equity, a rate base of $531 million, and a test year ended March 31, 2024, with certain pro-forma adjustments expected through the true-up date of December 31, 2024. The MoPSC proceeding relating to the proposed natural gas delivery service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by August 2025 and new rates effective by September 2025.
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 August 2024, the ICC staff submitted its calculation of the reconciliation adjustment, recommending approval of Ameren Illinois’ request. 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.
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, approving revenue requirements for electric distribution services for 2024, 2025, 2026, and 2027 of $1,196 million, $1,282 million, $1,350 million, and $1,397 million, respectively. New rates became effective in late June 2024. 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. Also, in January 2024, Ameren Illinois filed an appeal of the December 2023 ICC order, including the 8.72% ROE, and subsequently updated the appeal filing in September 2024 to include the June 2024 rehearing order regarding the inclusion of an asset associated with other postretirement benefits in the rate base to the Illinois Appellate Court for the Fifth Judicial District. The court is under no deadline to address the appeal. In September 2024, Ameren Illinois filed an update to its revised Grid Plan and a request to update the associated MYRP revenue requirements for 2024, 2025, 2026, and 2027 of $1,215 million, $1,299 million, $1,385 million, and $1,444 million, respectively. An ICC decision on the revised Grid Plan and updated revenue requirements is expected in December 2024 with rates effective in January 2025. 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.
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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.
In May 2024, Ameren Illinois filed its annual electric energy-efficiency formula rate update to increase its rates by $26 million with the ICC. In September 2024, the ICC staff filed a recommendation supporting Ameren Illinois’ requested increase. An ICC decision in this proceeding is required by December 2024, with new rates effective January 2025.
In October 2024, the FERC issued an order, which decreased the allowed base ROE for FERC-regulated transmission rate base under the MISO tariff from 10.02% to 9.98% and required refunds, with interest, for the periods from November 2013 to February 2015 and from late September 2016 forward. As a result, Ameren and Ameren Illinois recognized reductions to electric revenues of $10 million and $7 million, respectively, and recognized interest expense of $2 million and $1 million, respectively, on their statements of income during the third quarter of 2024. As of September 30, 2024, Ameren and Ameren Illinois had recorded current regulatory liabilities on their balance sheets of $12 million and $8 million, respectively, to reflect the expected refunds, including interest, associated with the allowed base ROE set by the October 2024 order. The decrease in the FERC-allowed base ROE resulting from the October 2024 order is not material to Ameren Missouri’s results of operations, financial position, or liquidity.
In 2021, the MISO issued a report outlining a preliminary long-range transmission planning roadmap of projects through 2039, which considers the rapidly changing generation mix within MISO resulting from significant additions of renewable generation, actual and expected generation plant closures, and state mandates or goals for clean energy or carbon emissions reductions. In July 2022, the MISO approved the first tranche of projects under the roadmap. A portion of these projects were assigned to various utilities, of which Ameren was awarded projects that are estimated to cost approximately $1.8 billion, based on the MISO’s cost estimate. Related to these projects, Ameren began substation upgrades in May 2024 in advance of transmission line construction, which is expected to begin in 2026, with forecasted completion dates near the end of this decade. In addition, the MISO awarded two competitive bid projects to ATXI in the fourth quarter of 2023 and one in April 2024 that represent a total estimated investment of approximately $220 million for ATXI. 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. 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 expects to construct within the MoPSC’s jurisdiction. A decision by the MoPSC is expected by mid-2025. In September 2024, the MISO revised a proposed first set of second tranche projects with estimated costs of $21.8 billion, which includes projects located in our service territories of $3.6 billion, based on the MISO’s cost estimate. The MISO is expected to approve this set of projects by the end of 2024. The MISO expects to begin developing an additional set of second tranche projects in 2025.
For further information on the matters discussed above, see Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report, and the Outlook section below.
RESULTS OF OPERATIONS
Our results of operations and financial position are affected by many factors. Economic conditions, energy-efficiency investments by our customers and by us, technological advances, distributed generation, and the actions of key customers can significantly affect the demand for our services. Ameren and Ameren Missouri results are also affected by seasonal fluctuations in winter heating and summer cooling demands and by weather conditions, such as storms, as well as by energy center maintenance outages. Additionally, fluctuations in interest rates and conditions in the capital and credit markets affect our cost of borrowing, our pension and postretirement benefits costs, the cash surrender value of COLI, and the asset value of Ameren Missouri’s nuclear decommissioning trust fund. Almost all of Ameren’s revenues are subject to state or federal regulation. This regulation has a material impact on the rates we charge customers for our services. Our results of operations, financial position, and liquidity are affected by our ability to align our overall spending, both operating and capital, with the frameworks established by our regulators. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K for additional information regarding Ameren Missouri’s, Ameren Illinois’, and ATXI’s regulatory mechanisms.
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Although the pace of inflation has slowed recently, we are still observing elevated inflation levels that continue to put pressure on the prices of labor, services, materials, and supplies, as well as elevated interest rates. Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel, purchased power, and natural gas supply. Additionally, for certain non-commodity cost changes, the use of trackers, riders, formula ratemaking, and future test years, as applicable, mitigates our exposure.
Ameren Missouri principally uses coal and enriched uranium for fuel in its electric generation operations and purchases natural gas for its customers. Ameren Illinois purchases power and natural gas for its customers. The prices for these commodities can fluctuate significantly because of the global economic and political environment, weather, supply, demand, and many other factors. We have natural gas cost recovery mechanisms for our Illinois and Missouri natural gas distribution businesses, a purchased power cost recovery mechanism for Ameren Illinois’ electric distribution business, and a FAC for Ameren Missouri’s electric business.
We employ various risk management strategies to reduce our exposure to commodity risk and other risks inherent in our business. The reliability of Ameren Missouri’s energy centers and our transmission and distribution systems, and the level and timing of operations and maintenance costs and capital investment, are key factors that we seek to manage in order to optimize our results of operations, financial position, and liquidity.
Earnings Summary
The following table presents a summary of Ameren’s earnings for the three and nine months ended September 30, 2024 and 2023:

| Three Months |  | Nine Months
| 2024 |  | 2023 |  | 2024 |  | 2023
Net income attributable to Ameren common shareholders | $ | 456 |  |  | $ | 493 |  |  | $ | 975 |  |  | $ | 994 |
Earnings per common share – diluted | 1.70 |  |  | 1.87 |  |  | 3.65 |  |  | 3.78 |

Net income attributable to Ameren common shareholders decreased $37 million and earnings per diluted share decreased 17 cents in the three months ended September 30, 2024, compared with the year-ago period. The decrease was due to net income decreases of $30 million and $10 million at Ameren Missouri and Ameren Illinois Electric Distribution, respectively, and an increase in net loss of $5 million at Ameren Illinois Natural Gas. These decreases were partially offset by a net income increase of $4 million at Ameren Transmission and a decrease in net loss of $4 million for activity not reported as part of a segment, primarily at Ameren (parent).
Net income attributable to Ameren common shareholders decreased $19 million and earnings per diluted share decreased 13 cents in the nine months ended September 30, 2024, compared with the year-ago period. The decrease was due to net income decreases of $20 million and $7 million at Ameren Illinois Electric Distribution and Ameren Missouri, respectively, and an increase in net loss of $13 million for activity not reported as part of a segment, primarily at Ameren (parent). These decreases were partially offset by net income increases of $12 million and $9 million at Ameren Transmission and Ameren Illinois Natural Gas.
Earnings per diluted share were unfavorably affected in the three and nine months ended September 30, 2024, compared to the year-ago periods (except where a specific period is referenced), by:
•a charge recorded by Ameren Missouri, included in other operation and maintenance expenses, related to an agreement in principle with the United States Department of Justice, which, if approved, would resolve all outstanding claims in the NSR and Clean Air Act litigation related to the Rush Island Energy Center, see Note 9 - Commitments and Contingencies under Part 1, Item 1, of this report for more information (13 cents and 17 cents per share, respectively);
•increased financing costs primarily at Ameren Missouri and Ameren (parent), largely due to higher long-term debt balances and interest rates, partially offset by lower levels of short-term borrowings (5 cents and 12 cents per share, respectively);
•lower revenue at Ameren Illinois Electric Distribution due to a lower recognized ROE under the MYRP (3 cents and 7 cents per share, respectively);
•increased weighted-average basic common shares outstanding resulting from issuances of common shares (3 cents and 6 cents per share, respectively);
•the result of the October 2024 FERC order reducing the allowed base ROE for FERC regulated transmission rate base under the MISO tariff, which decreased Ameren Transmission earnings (4 cents per share for both periods);
•decreased retail electric sales volumes at Ameren Missouri, primarily due to milder summer temperatures, partially offset by increased retail electric sales volumes, excluding the estimated effects of weather and customer energy-efficiency programs (estimated at 3 cents for the three months ended September 30, 2024);
•increased taxes other than income taxes at Ameren Missouri, largely resulting from the absence in 2024 of employee retention tax credits received under the Coronavirus Aid, Relief, and Economic Security Act (1 cent and 2 cents per share, respectively); and
•absence of recovery of previously incurred expenses at Ameren Illinois Electric Distribution (2 cents per share for the nine months ended September 30, 2024).
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Earnings per diluted share were favorably affected in the three and nine months ended September 30, 2024, compared to the year-ago periods (except where a specific period is referenced), by:
•increased rate base investments at Ameren Transmission, which increased earnings in this segment (5 cents and 12 cents per share, respectively);
•increased allowance for equity funds used during construction and increased base rate revenues for the inclusion of previously deferred PISA and RESRAM interest charges pursuant to the June 2023 MoPSC electric rate order effective July 9, 2023, partially offset by increased interest charges resulting from lower deferrals in the nine months ended September 30, 2024, related to infrastructure investments associated with the PISA and RESRAM, at Ameren Missouri (5 cents and 11 cents per share, respectively);
•increased base rate revenues at Ameren Missouri effective July 9, 2023, pursuant to the June 2023 MoPSC electric rate order, partially offset by the net effect of amortization of previously deferred depreciation expense under the PISA and RESRAM, financing costs otherwise recoverable under the PISA and RESRAM, a lower base level of expenses included in trackers, and the net recovery for amounts associated with the reduction in sales volumes resulting from MEEIA programs (9 cents per share for the nine months ended September 30, 2024);
•decreased other operations and maintenance expenses not subject to formula rates, riders, or trackers, excluding a charge related to the NSR and Clean Air Act litigation discussed above, primarily at Ameren Missouri and Ameren Illinois Natural Gas, largely because of lower storm costs, an increase in the cash surrender value of COLI, and disciplined cost management including lower labor costs from decreased headcount, decreased use of contractors, and lower amortization of refueling costs for the Callaway Energy Center (7 cents and 1 cent per share, respectively);
•increased retail electric sales volumes at Ameren Missouri, primarily due to higher sales excluding customer energy-efficiency programs (estimated at 5 cents per share for the nine months ended September 30, 2024); and
•increased base rate revenues at Ameren Illinois Natural Gas effective November 28, 2023, pursuant to the November 2023 ICC natural gas rate order, partially offset by increased depreciation and amortization expenses included in base rates (4 cents per share for the nine months ended September 30, 2024).
The cents per share variances above are presented based on the weighted-average basic common shares outstanding in the three and nine months ended September 30, 2023, and do not reflect the impact of dilution on earnings per share, unless otherwise noted. The amounts above other than variances related to income taxes have been presented net of income taxes using Ameren’s 2024 blended federal and state statutory tax rate of 26%. For additional details regarding the Ameren Companies’ results of operations, including explanations of Operating Revenues for both Electric Revenues and Natural Gas Revenues; Fuel and Purchased Power Expenses; Other Operations and Maintenance Expenses; Depreciation and Amortization Expenses; Taxes Other Than Income Taxes; Other Income, Net; Interest Charges; and Income Taxes, see the major headings below.
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Below is Ameren’s table of income statement components by segment for the three and nine months ended September 30, 2024 and 2023:

| Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission |  | Other / Intersegment Eliminations |  | Ameren
Three Months 2024: |  |  |  |  |  |  |  |  |  |  |
Electric revenues | $ | 1,324 |  |  | $ | 552 |  |  | $ | — |  |  | $ | 210 |  |  | $ | (51) |  |  | $ | 2,035 |
Natural gas revenues | 18 |  |  | — |  |  | 121 |  |  | — |  |  | (1) |  |  | 138 |
Fuel and purchased power | (334) |  |  | (204) |  |  | — |  |  | — |  |  | 39 |  |  | (499) |
Natural gas purchased for resale | (4) |  |  | — |  |  | (26) |  |  | — |  |  | — |  |  | (30) |
Other operations and maintenance expenses | (288) |  |  | (163) |  |  | (51) |  |  | (19) |  |  | 1 |  |  | (520) |
Depreciation and amortization expenses | (220) |  |  | (92) |  |  | (32) |  |  | (42) |  |  | (2) |  |  | (388) |
Taxes other than income taxes | (109) |  |  | (21) |  |  | (14) |  |  | (2) |  |  | (4) |  |  | (150) |
Operating income (loss) | 387 |  |  | 72 |  |  | (2) |  |  | 147 |  |  | (18) |  |  | 586 |
Other income, net | 51 |  |  | 23 |  |  | 6 |  |  | 8 |  |  | 13 |  |  | 101 |
Interest charges | (62) |  |  | (25) |  |  | (16) |  |  | (31) |  |  | (39) |  |  | (173) |
Income (taxes) benefit | 6 |  |  | (14) |  |  | 2 |  |  | (34) |  |  | (17) |  |  | (57) |
Net income (loss) | 382 |  |  | 56 |  |  | (10) |  |  | 90 |  |  | (61) |  |  | 457 |
Noncontrolling interests – preferred stock dividends | (1) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1) |
Net income (loss) attributable to Ameren common shareholders | $ | 381 |  |  | $ | 56 |  |  | $ | (10) |  |  | $ | 90 |  |  | $ | (61) |  |  | $ | 456 |
Three Months 2023: |  |  |  |  |  |  |  |  |  |  |
Electric revenues | $ | 1,219 |  |  | $ | 558 |  |  | $ | — |  |  | $ | 188 |  |  | $ | (44) |  |  | $ | 1,921 |
Natural gas revenues | 18 |  |  | — |  |  | 122 |  |  | — |  |  | (1) |  |  | 139 |
Fuel and purchased power | (233) |  |  | (233) |  |  | — |  |  | — |  |  | 36 |  |  | (430) |
Natural gas purchased for resale | (4) |  |  | — |  |  | (26) |  |  | — |  |  | — |  |  | (30) |
Other operations and maintenance expenses | (256) |  |  | (132) |  |  | (56) |  |  | (15) |  |  | (11) |  |  | (470) |
Depreciation and amortization expenses | (217) |  |  | (89) |  |  | (26) |  |  | (34) |  |  | (3) |  |  | (369) |
Taxes other than income taxes | (108) |  |  | (21) |  |  | (12) |  |  | (2) |  |  | (4) |  |  | (147) |
Operating income (loss) | 419 |  |  | 83 |  |  | 2 |  |  | 137 |  |  | (27) |  |  | 614 |
Other income, net | 44 |  |  | 24 |  |  | 8 |  |  | 7 |  |  | 18 |  |  | 101 |
Interest charges | (63) |  |  | (23) |  |  | (15) |  |  | (25) |  |  | (26) |  |  | (152) |
Income (taxes) benefit | 12 |  |  | (18) |  |  | — |  |  | (33) |  |  | (30) |  |  | (69) |
Net income (loss) | 412 |  |  | 66 |  |  | (5) |  |  | 86 |  |  | (65) |  |  | 494 |
Noncontrolling interests – preferred stock dividends | (1) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1) |
Net income (loss) attributable to Ameren common shareholders | $ | 411 |  |  | $ | 66 |  |  | $ | (5) |  |  | $ | 86 |  |  | $ | (65) |  |  | $ | 493 |

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| Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission |  | Other / Intersegment Eliminations |  | Ameren
Nine Months 2024: |  |  |  |  |  |  |  |  |  |  |
Electric revenues | $ | 2,902 |  |  | $ | 1,567 |  |  | $ | — |  |  | $ | 586 |  |  | $ | (135) |  |  | $ | 4,920 |
Natural gas revenues | 103 |  |  | — |  |  | 660 |  |  | — |  |  | (1) |  |  | 762 |
Fuel and purchased power | (689) |  |  | (564) |  |  | — |  |  | — |  |  | 99 |  |  | (1,154) |
Natural gas purchased for resale | (41) |  |  | — |  |  | (173) |  |  | — |  |  | — |  |  | (214) |
Other operations and maintenance expenses | (789) |  |  | (452) |  |  | (168) |  |  | (54) |  |  | 8 |  |  | (1,455) |
Depreciation and amortization expenses | (623) |  |  | (278) |  |  | (98) |  |  | (121) |  |  | (5) |  |  | (1,125) |
Taxes other than income taxes | (287) |  |  | (57) |  |  | (55) |  |  | (6) |  |  | (11) |  |  | (416) |
Operating income (loss) | 576 |  |  | 216 |  |  | 166 |  |  | 405 |  |  | (45) |  |  | 1,318 |
Other income, net | 144 |  |  | 72 |  |  | 20 |  |  | 14 |  |  | 43 |  |  | 293 |
Interest charges | (187) |  |  | (73) |  |  | (46) |  |  | (89) |  |  | (97) |  |  | (492) |
Income (taxes) benefit | 4 |  |  | (41) |  |  | (38) |  |  | (89) |  |  | 24 |  |  | (140) |
Net income (loss) | 537 |  |  | 174 |  |  | 102 |  |  | 241 |  |  | (75) |  |  | 979 |
Noncontrolling interests – preferred stock dividends | (3) |  |  | (1) |  |  | — |  |  | — |  |  | — |  |  | (4) |
Net income (loss) attributable to Ameren common shareholders | $ | 534 |  |  | $ | 173 |  |  | $ | 102 |  |  | $ | 241 |  |  | $ | (75) |  |  | $ | 975 |
Nine Months 2023: |  |  |  |  |  |  |  |  |  |  |
Electric revenues | $ | 2,978 |  |  | $ | 1,722 |  |  | $ | — |  |  | $ | 512 |  |  | $ | (116) |  |  | $ | 5,096 |
Natural gas revenues | 123 |  |  | — |  |  | 665 |  |  | — |  |  | (2) |  |  | 786 |
Fuel and purchased power | (843) |  |  | (766) |  |  | — |  |  | — |  |  | 91 |  |  | (1,518) |
Natural gas purchased for resale | (60) |  |  | — |  |  | (220) |  |  | — |  |  | — |  |  | (280) |
Other operations and maintenance expenses | (732) |  |  | (394) |  |  | (173) |  |  | (44) |  |  | (25) |  |  | (1,368) |
Depreciation and amortization expenses | (579) |  |  | (260) |  |  | (79) |  |  | (101) |  |  | (5) |  |  | (1,024) |
Taxes other than income taxes | (276) |  |  | (57) |  |  | (48) |  |  | (6) |  |  | (11) |  |  | (398) |
Operating income (loss) | 611 |  |  | 245 |  |  | 145 |  |  | 361 |  |  | (68) |  |  | 1,294 |
Other income, net | 85 |  |  | 74 |  |  | 24 |  |  | 21 |  |  | 57 |  |  | 261 |
Interest charges | (166) |  |  | (66) |  |  | (41) |  |  | (70) |  |  | (70) |  |  | (413) |
Income (taxes) benefit | 14 |  |  | (59) |  |  | (35) |  |  | (83) |  |  | 19 |  |  | (144) |
Net income (loss) | 544 |  |  | 194 |  |  | 93 |  |  | 229 |  |  | (62) |  |  | 998 |
Noncontrolling interests – preferred stock dividends | (3) |  |  | (1) |  |  | — |  |  | — |  |  | — |  |  | (4) |
Net income (loss) attributable to Ameren common shareholders | $ | 541 |  |  | $ | 193 |  |  | $ | 93 |  |  | $ | 229 |  |  | $ | (62) |  |  | $ | 994 |

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Below is Ameren Illinois’ table of income statement components by segment for the three and nine months ended September 30, 2024 and 2023:

| Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Illinois Transmission |  | Other / Intersegment Eliminations |  | Ameren Illinois
Three Months 2024: |  |  |  |  |  |  |  |  |
Electric revenues | $ | 552 |  |  | $ | — |  |  | $ | 155 |  |  | $ | (35) |  |  | $ | 672 |
Natural gas revenues | — |  |  | 121 |  |  | — |  |  | — |  |  | 121 |
Purchased power | (204) |  |  | — |  |  | — |  |  | 35 |  |  | (169) |
Natural gas purchased for resale | — |  |  | (26) |  |  | — |  |  | — |  |  | (26) |
Other operations and maintenance expenses | (163) |  |  | (51) |  |  | (15) |  |  | — |  |  | (229) |
Depreciation and amortization expenses | (92) |  |  | (32) |  |  | (31) |  |  | — |  |  | (155) |
Taxes other than income taxes | (21) |  |  | (14) |  |  | (2) |  |  | — |  |  | (37) |
Operating income (loss) | 72 |  |  | (2) |  |  | 107 |  |  | — |  |  | 177 |
Other income, net | 23 |  |  | 6 |  |  | 8 |  |  | — |  |  | 37 |
Interest charges | (25) |  |  | (16) |  |  | (22) |  |  | — |  |  | (63) |
Income (taxes) benefit | (14) |  |  | 2 |  |  | (25) |  |  | — |  |  | (37) |
Net income (loss) attributable to Ameren common shareholders | $ | 56 |  |  | $ | (10) |  |  | $ | 68 |  |  | $ | — |  |  | $ | 114 |
Three Months 2023: |  |  |  |  |  |  |  |  |
Electric revenues | $ | 558 |  |  | $ | — |  |  | $ | 136 |  |  | $ | (33) |  |  | $ | 661 |
Natural gas revenues | — |  |  | 122 |  |  | — |  |  | — |  |  | 122 |
Purchased power | (233) |  |  | — |  |  | — |  |  | 33 |  |  | (200) |
Natural gas purchased for resale | — |  |  | (26) |  |  | — |  |  | — |  |  | (26) |
Other operations and maintenance expenses | (132) |  |  | (56) |  |  | (12) |  |  | — |  |  | (200) |
Depreciation and amortization expenses | (89) |  |  | (26) |  |  | (24) |  |  | — |  |  | (139) |
Taxes other than income taxes | (21) |  |  | (12) |  |  | (1) |  |  | — |  |  | (34) |
Operating income | 83 |  |  | 2 |  |  | 99 |  |  | — |  |  | 184 |
Other income, net | 24 |  |  | 8 |  |  | 5 |  |  | — |  |  | 37 |
Interest charges | (23) |  |  | (15) |  |  | (16) |  |  | — |  |  | (54) |
Income (taxes) benefit | (18) |  |  | — |  |  | (24) |  |  | — |  |  | (42) |
Net income (loss) attributable to Ameren common shareholders | $ | 66 |  |  | $ | (5) |  |  | $ | 64 |  |  | $ | — |  |  | $ | 125 |
Nine Months 2024: |  |  |  |  |  |  |  |  |
Electric revenues | $ | 1,567 |  |  | $ | — |  |  | $ | 422 |  |  | $ | (90) |  |  | $ | 1,899 |
Natural gas revenues | — |  |  | 660 |  |  | — |  |  | — |  |  | 660 |
Purchased power | (564) |  |  | — |  |  | — |  |  | 90 |  |  | (474) |
Natural gas purchased for resale | — |  |  | (173) |  |  | — |  |  | — |  |  | (173) |
Other operations and maintenance expenses | (452) |  |  | (168) |  |  | (43) |  |  | — |  |  | (663) |
Depreciation and amortization expenses | (278) |  |  | (98) |  |  | (86) |  |  | — |  |  | (462) |
Taxes other than income taxes | (57) |  |  | (55) |  |  | (4) |  |  | — |  |  | (116) |
Operating income | 216 |  |  | 166 |  |  | 289 |  |  | — |  |  | 671 |
Other income, net | 72 |  |  | 20 |  |  | 13 |  |  | — |  |  | 105 |
Interest charges | (73) |  |  | (46) |  |  | (59) |  |  | — |  |  | (178) |
Income taxes | (41) |  |  | (38) |  |  | (65) |  |  | — |  |  | (144) |
Net income | 174 |  |  | 102 |  |  | 178 |  |  | — |  |  | 454 |
Preferred stock dividends | (1) |  |  | — |  |  | — |  |  | — |  |  | (1) |
Net income attributable to common shareholder | $ | 173 |  |  | $ | 102 |  |  | $ | 178 |  |  | $ | — |  |  | $ | 453 |

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| Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Illinois Transmission |  | Other / Intersegment Eliminations |  | Ameren Illinois
Nine Months 2023: |  |  |  |  |  |  |  |  |
Electric revenues | $ | 1,722 |  |  | $ | — |  |  | $ | 363 |  |  | $ | (87) |  |  | $ | 1,998 |
Natural gas revenues | — |  |  | 665 |  |  | — |  |  | — |  |  | 665 |
Purchased power | (766) |  |  | — |  |  | — |  |  | 87 |  |  | (679) |
Natural gas purchased for resale | — |  |  | (220) |  |  | — |  |  | — |  |  | (220) |
Other operations and maintenance expenses | (394) |  |  | (173) |  |  | (36) |  |  | — |  |  | (603) |
Depreciation and amortization expenses | (260) |  |  | (79) |  |  | (71) |  |  | — |  |  | (410) |
Taxes other than income taxes | (57) |  |  | (48) |  |  | (3) |  |  | — |  |  | (108) |
Operating income | 245 |  |  | 145 |  |  | 253 |  |  | — |  |  | 643 |
Other income, net | 74 |  |  | 24 |  |  | 17 |  |  | — |  |  | 115 |
Interest charges | (66) |  |  | (41) |  |  | (44) |  |  | — |  |  | (151) |
Income taxes | (59) |  |  | (35) |  |  | (60) |  |  | — |  |  | (154) |
Net income | 194 |  |  | 93 |  |  | 166 |  |  | — |  |  | 453 |
Preferred stock dividends | (1) |  |  | — |  |  | — |  |  | — |  |  | (1) |
Net income attributable to common shareholder | $ | 193 |  |  | $ | 93 |  |  | $ | 166 |  |  | $ | — |  |  | $ | 452 |

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Operating Revenues
The following table presents the increases (decreases) by Ameren segment for electric and natural gas revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods:

Three Months | Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission(a) |  | Other /Intersegment Eliminations |  | Ameren |  |  |  |  |
Electric revenue change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Base rates (estimate)(b) | $ | 2 |  |  | $ | 8 |  |  | $ | — |  |  | $ | 18 |  |  | $ | — |  |  | $ | 28 |  |  |  |  |  |
Effect of weather (estimate)(c) | (18) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (18) |  |  |  |  |  |
Retail sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA) | 6 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 6 |  |  |  |  |  |
Off-system sales, capacity, and FAC revenues, net | 112 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 112 |  |  |  |  |  |
Ameren Illinois energy-efficiency program investment revenues | — |  |  | 3 |  |  | — |  |  | — |  |  | — |  |  | 3 |  |  |  |  |  |
Electric deferred income tax adjustment(d) | — |  |  | (9) |  |  | — |  |  | — |  |  | — |  |  | (9) |  |  |  |  |  |
Other | 4 |  |  | 3 |  |  | — |  |  | 4 |  |  | (4) |  |  | 7 |  |  |  |  |  |
Cost recovery mechanisms – offset in fuel and purchased power(e) | (11) |  |  | (29) |  |  | — |  |  | — |  |  | (3) |  |  | (43) |  |  |  |  |  |
Other cost recovery mechanisms(f) | 10 |  |  | 18 |  |  | — |  |  | — |  |  | — |  |  | 28 |  |  |  |  |  |
Total electric revenue change | $ | 105 |  |  | $ | (6) |  |  | $ | — |  |  | $ | 22 |  |  | $ | (7) |  |  | $ | 114 |  |  |  |  |  |
Natural gas revenue change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Base rates (estimate) | $ | — |  |  | $ | — |  |  | $ | 8 |  |  | $ | — |  |  | $ | — |  |  | $ | 8 |  |  |  |  |  |
Change in rate design (estimate) | — |  |  | — |  |  | (9) |  |  | — |  |  | — |  |  | (9) |  |  |  |  |  |
Total natural gas revenue change | $ | — |  |  | $ | — |  |  | $ | (1) |  |  | $ | — |  |  | $ | — |  |  | $ | (1) |  |  |  |  |  |
Nine Months |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Electric revenue change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Base rates (estimate)(b) | $ | 62 |  |  | $ | 24 |  |  | $ | — |  |  | $ | 63 |  |  | $ | — |  |  | $ | 149 |  |  |  |  |  |
Effect of weather (estimate)(c) | 3 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 3 |  |  |  |  |  |
Retail sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA) | 17 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 17 |  |  |  |  |  |
Off-system sales, capacity, and FAC revenues, net | (135) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (135) |  |  |  |  |  |
Ameren Illinois energy-efficiency program investment revenues | — |  |  | 14 |  |  | — |  |  | — |  |  | — |  |  | 14 |  |  |  |  |  |
Electric deferred income tax adjustment(d) | — |  |  | (18) |  |  | — |  |  | — |  |  | — |  |  | (18) |  |  |  |  |  |
Other | 3 |  |  | — |  |  | — |  |  | 11 |  |  | (11) |  |  | 3 |  |  |  |  |  |
Cost recovery mechanisms – offset in fuel and purchased power(e) | (49) |  |  | (202) |  |  | — |  |  | — |  |  | (8) |  |  | (259) |  |  |  |  |  |
Other cost recovery mechanisms(f) | 23 |  |  | 27 |  |  | — |  |  | — |  |  | — |  |  | 50 |  |  |  |  |  |
Total electric revenue change | $ | (76) |  |  | $ | (155) |  |  | $ | — |  |  | $ | 74 |  |  | $ | (19) |  |  | $ | (176) |  |  |  |  |  |
Natural gas revenue change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Base rates (estimate) | $ | — |  |  | $ | — |  |  | $ | 43 |  |  | $ | — |  |  | $ | — |  |  | $ | 43 |  |  |  |  |  |
Change in rate design (estimate) | — |  |  | — |  |  | (3) |  |  | — |  |  | — |  |  | (3) |  |  |  |  |  |
Effect of weather (estimate)(c) | 1 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  |  |  |  |
Other | — |  |  | — |  |  | 3 |  |  | — |  |  | 1 |  |  | 4 |  |  |  |  |  |
Cost recovery mechanisms – offset in natural gas purchased for resale(e) | (20) |  |  | — |  |  | (47) |  |  | — |  |  | — |  |  | (67) |  |  |  |  |  |
Other cost recovery mechanisms(f) | (1) |  |  | — |  |  | (1) |  |  | — |  |  | — |  |  | (2) |  |  |  |  |  |
Total natural gas revenue change | $ | (20) |  |  | $ | — |  |  | $ | (5) |  |  | $ | — |  |  | $ | 1 |  |  | $ | (24) |  |  |  |  |  |

(a)Includes an increase in transmission revenues of $19 million and $59 million at Ameren Illinois for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods.
(b)For Ameren Illinois Electric Distribution and Ameren Transmission, base rates include increases or decreases in operating revenues related to the revenue requirement reconciliation adjustment under the MYRP and formula rates, respectively. For Ameren Missouri, base rates exclude an increase for the recovery of lost electric revenue, less the associated fuel and purchased power expenses, resulting from the MEEIA customer energy-efficiency programs and a decrease in base rates for RESRAM. These changes in Ameren Missouri base rates are included in the “Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)” and “Cost recovery mechanisms - offset in fuel and purchased power” line items, respectively.
(c)Represents the estimated variation resulting primarily from changes in cooling and heating degree-days on electric and natural gas demand compared with the year-ago periods; this variation is based on temperature readings from National Oceanic and Atmospheric Administration weather stations at local airports in our service territories.
(d)The electric deferred income tax adjustment relates to the remaining balance of certain excess deferred income taxes that will be amortized through 2025. Offsetting expense increases or decreases are reflected within the "Income Taxes" section of the statement of income. This item has no overall impact on earnings.
(e)Electric and natural gas revenue changes are offset by corresponding changes in “Fuel and purchased power” and “Natural gas purchased for resale” on the statement of income. For the three and nine months ended September 30, 2024, activity in Other/Intersegment Eliminations of $3 million and $8 million, respectively, represents the changes in eliminations of related-party transactions between Ameren Missouri, Ameren Illinois, and ATXI (-$1 million and -$5 million, respectively), as well as changes in Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution (-$2 million and -$3 million, respectively). See Note 8 – Related-party Transactions and Note 14 – Segment Information under Part I, Item 1, of this report for additional information on intersegment eliminations. These items have no overall impact on earnings.
(f)Offsetting expense increases or decreases are reflected in “Other operations and maintenance,” “Depreciation and amortization,” or in “Taxes other than income taxes,” within the “Operating Expenses” section of the statement of income. These items have no overall impact on earnings.
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Electric Revenues
Ameren
Ameren’s electric revenues increased $114 million, or 6%, for the three months ended September 30, 2024, compared with the year-ago period, primarily due to increased revenues at Ameren Missouri and Ameren Transmission, partially offset by decreased revenues at Ameren Illinois Electric Distribution, as discussed below. Ameren’s electric revenues decreased $176 million, or 3%, for the nine months ended September 30, 2024, compared with the year-ago period, primarily due to decreased revenues at Ameren Illinois Electric Distribution and Ameren Missouri, partially offset by increased revenues at Ameren Transmission, as discussed below.
Ameren Transmission
Amer en Transmission’s electric revenues increased $22 million, or 12%, and $74 million, or 14%, for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods. Revenues were favorably affected by higher recoverable expenses
(+$15 million and +$40 million, respectively), increased capital investment (+$13 million and +$33 million, respectively), as evidenced by a 15% increase in rate base used to calculate the revenue requirement, and increased facility rental revenues (+$4 million and +$11 million, respectively) related to ATXI’s transmission operations control center, which was placed in service in December 2023. ATXI provides affiliates with access to this facility. Rental revenues associated with this facility are affiliate transactions and eliminated in consolidation for Ameren’s consolidated financial statements. See Note 8 – Related-party Transactions under Part I, Item 1, of this report for additional information. Revenues were unfavorably affected by a decrease in the allowed base ROE under the MISO tariff resulting from the October 2024 FERC order, which included customer refunds for certain historical periods (-$10 million and -$10 million, respectively). See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information regarding the FERC complaint cases.
Ameren Missouri
Ameren Missouri’s electric revenues increased $105 million, or 9%, for the three months ended September 30, 2024, and decreased $76 million, or 3%, for the nine months ended September 30, 2024, compared with the year-ago periods.
The following items had an unfavorable effect on Ameren Missouri’s electric revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•“Off-system sales, capacity and FAC revenues, net” decreased $135 million for the nine months ended September 30, 2024, primarily due to lower winter and spring capacity prices, partially offset by higher summer capacity prices which were set by annual MISO auctions. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC is included within “Off-system sales, capacity, and FAC revenues, net” and “Energy costs (excluding the estimated effect of weather)” in fuel and purchased power.
•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” decreased $11 million and $49 million, respectively, due to decreased revenue related to the amortization of costs previously deferred under the FAC that were reflected in customer rates. The changes to “Cost recovery mechanisms - offset in fuel and purchased power” are fully offset by changes to “Cost recovery mechanisms - offset in electric revenue” in fuel and purchased power.
•The aggregate effect of weather decreased revenues an estimated $18 million for the three months ended September 30, 2024, due to milder summer temperatures as cooling degree days decreased 5%.
The following items had a favorable effect on Ameren Missouri’s electric revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•“Off-system sales, capacity and FAC revenues, net” increased $112 million for the three months ended September 30, 2024, primarily due to higher summer capacity prices which were set by annual MISO auctions. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC is included within “Off-system sales, capacity, and FAC revenues, net” and “Energy costs (excluding the estimated effect of weather)” in fuel and purchased power.
•Higher electric base rates, resulting from the June 2023 MoPSC electric rate order effective July 9, 2023, increased revenues an estimated $2 million and $62 million, respectively.
•Revenues associated with other cost recovery mechanisms increased $10 million and $23 million, respectively, primarily due to an increase in RESRAM revenues in both periods and an increase in excise taxes due to increased retail sales revenue for the nine months ended September 30, 2024.
•Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues increased an estimated $6 million and $17 million, respectively, for the three and nine months ended September 30, 2024, due to an increase in retail sales volumes, which were, in part, favorably affected by the absence of customer outages resulting from major storms experienced throughout the service territory in July and August 2023 and an additional day in 2024 as a result of the leap year. The increase is partially offset by lower realized prices due to changes in customer usage patterns and economic development discounts.
•Other revenues increased by $3 million in both periods, primarily due to increased mutual assistance related to storm recovery.
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•The aggregate effect of weather increased revenues an estimated $3 million for the nine months ended September 30, 2024, due to warmer spring temperatures largely offset by milder summer temperatures and warmer winter temperatures, as cooling degree days increased 6% and heating degree days decreased 6%.
Ameren Illinois
Ameren Illinois’ electric revenues increased $11 million, or 2%, for the three months ended September 30, 2024, compared with the year-ago period, driven by increased revenues at Ameren Illinois Transmission, partially offset by decreased revenues at Ameren Illinois Electric Distribution. Ameren Illinois’ electric revenues decreased $99 million, or 5%, for the nine months ended September 30, 2024, compared with the year-ago period, driven by decreased revenues at Ameren Illinois Electric Distribution, partially offset by increased revenues at Ameren Illinois Transmission.
Ameren Illinois Electric Distribution
Ameren Illinois Electric Distribution’s revenues decreased $6 million, or 1%, and $155 million, or 9%, for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods.
The following items had an unfavorable effect on Ameren Illinois Electric Distribution’s revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods:
•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” decreased $29 million and $202 million, respectively, due to decreased purchased power expenses recovered from customers. The decreases in electric revenues are fully offset by decreases in purchased power expenses under cost recovery mechanisms for purchased power, as discussed below.
•Pursuant to an ICC order, revenues decreased $9 million and $18 million, respectively, due to an increase in the amortization rate for certain excess deferred income taxes.
The following items had a favorable effect on Ameren Illinois Electric Distribution’s revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•Other cost recovery mechanisms increased revenues by $18 million and $27 million, respectively, primarily due to a higher amount of bad debt and purchased receivables from alternative retail electric suppliers included in customer rates pursuant to their associated riders, partially offset by lower environmental remediation revenues.
•Base rates increased revenues by $8 million and $24 million, respectively, primarily due to higher recoverable non-purchased power expenses (+$16 million and +$41 million, respectively) and increased capital investment of $1 million for the nine months ended September 30, 2024, partially offset by a lower recognized ROE (-$8 million and -$18 million, respectively). The MYRP utilizes a fixed ROE approved by the ICC of 8.72%, with adjustments for any performance incentives and penalties, while the IEIMA formula-based ROE was based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points (estimated at 9.80% for the nine months ended September 30, 2023).
•Revenues associated with customer energy-efficiency program investments increased $3 million and $14 million, respectively, due to the recovery of program expenses (+$3 million and +$10 million, respectively), an increase in the ROE due to maximum achievement of the annual energy savings goals in 2023 of $3 million for the nine months ended September 30, 2024, and increased investment of $1 million for the nine months ended September 30, 2024.
Ameren Illinois Transmission
Ameren Illinois Transmission’s revenues increased $19 million, or 14%, and $59 million, or 16%, for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods. Base rate revenues were favorably affected by higher recoverable expen ses (+$16 million and +$41 million, respectively) and increased capital investment (+$10 million and +$25 million, respectively), as e videnced by a 16% increase in rate base used to calculate the revenue requirement. Base rate revenues were unfavorably affected by a decrease in the allowed base ROE under the MISO tariff resulting from the October 2024 FERC order, which included customer refunds for certain historical periods (-$7 million and -$7 million, respectively). See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information regarding the FERC complaint cases.
Natural Gas Revenues
Ameren
Ameren’s natural gas revenues were comparable for the three months ended September 30, 2024, and decreased $24 million, or 3%, for the nine months ended September 30, 2024, compared with the year-ago periods, due to decreased revenues at Ameren Missouri and Ameren Illinois Natural Gas, as discussed below.
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Ameren Missouri
Ameren Missouri’s natural gas revenues were comparable for the three months ended September 30, 2024, and decreased $20 million, or 16%, for the nine months ended September 30, 2024, compared with the year-ago periods. Revenues associated with “Cost recovery mechanisms – offset in natural gas purchased for resale” decreased $20 million for the nine months ended September 30, 2024, due to lower commodity prices and the absence of amortization of natural gas costs deferred under the PGA related to the extremely cold weather in mid-February 20 21. Changes in natural gas revenues under the PGA are fully offset by corresponding changes in natural gas purchased for resale expenses.
Ameren Illinois Natural Gas
Ameren Illinois Natural Gas’ revenues were comparable for the three months ended September 30, 2024, and decreased $5 million, or 1%, for the nine months ended September 30, 2024, compared with the year-ago periods.
The following items had an unfavorable effect on Ameren Illinois Natural Gas’ revenues for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•“Cost recovery mechanisms – offset in natural gas purchased for resale” decreased revenues $47 million for the nine months ended September 30, 2024, due to lower collection of natural gas costs previously deferred under the PGA. Changes in natural gas revenues under the PGA are fully offset by the decrease in natural gas purchased for resale expenses.
•The implementation of a change in rate design pursuant to the November 2023 natural gas rate order decreased revenues an estimated $9 million and $3 million, respectively. This change in rate design concentrates more revenues in the winter heating season due to an increase in volumetric rates and a decrease in fixed customer rates. As such, the change is not expected to materially affect annual earnings comparisons.
The decreases in Ameren Illinois Natural Gas’ revenues were partially offset by estimated increases of $8 million and $43 million for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, due to higher natural gas base rates as a result of the November 2023 natural gas rate order.
Fuel and Purchased Power
The following table presents the increases (decreases) by Ameren segment for fuel and purchased power for the three and nine months ended September 30, 2024, compared with the year-ago periods:

Three Months | Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission |  | Other /Intersegment Eliminations |  | Ameren |  |  |  |  |
Fuel and purchased power change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Energy costs (excluding the estimated effect of weather) | $ | 113 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 113 |  |  |  |  |  |
Effect of weather (estimate)(a) | (2) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (2) |  |  |  |  |  |
Effect of higher net energy costs included in base rates | 1 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  |  |  |  |
Cost recovery mechanisms – offset in electric revenue(b) | (11) |  |  | (29) |  |  | — |  |  | — |  |  | (3) |  |  | (43) |  |  |  |  |  |
Total fuel and purchased power change | $ | 101 |  |  | $ | (29) |  |  | $ | — |  |  | $ | — |  |  | $ | (3) |  |  | $ | 69 |  |  |  |  |  |
Nine Months |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Fuel and purchased power change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Energy costs (excluding the estimated effect of weather) | $ | (130) |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | (130) |  |  |  |  |  |
Effect of higher net energy costs included in base rates | 22 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 22 |  |  |  |  |  |
Other | 3 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 3 |  |  |  |  |  |
Cost recovery mechanisms – offset in electric revenue(b) | (49) |  |  | (202) |  |  | — |  |  | — |  |  | (8) |  |  | (259) |  |  |  |  |  |
Total fuel and purchased power change | $ | (154) |  |  | $ | (202) |  |  | $ | — |  |  | $ | — |  |  | $ | (8) |  |  | $ | (364) |  |  |  |  |  |

(a)Represents the estimated variation resulting primarily from changes in cooling and heating degree-days on electric demand compared with the year-ago periods; this variation is based on temperature readings from the National Oceanic and Atmospheric Administration weather stations at local airports in our service territories.
(b)“Cost recovery mechanisms — offset in electric revenue” changes are offset by corresponding changes in “Cost recovery mechanisms — offset in fuel and purchased power” in electric revenues. For the three and nine months ended September 30, 2024, activity in Other/Intersegment Eliminations of $3 million and $8 million, respectively, represents the changes in eliminations of related-party transactions between Ameren Missouri, Ameren Illinois, and ATXI (-$1 million and -$5 million, respectively), as well as changes in Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution (-$2 million and -$3 million, respectively). See Note 8 – Related-party Transactions and Note 14 – Segment Information under Part I, Item 1, of this report for additional information on intersegment eliminations. These items have no overall impact on earnings.
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Ameren
Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel and purchased power. Ameren’s electric fuel and purchased power expenses increased $69 million, or 16%, for the three months ended September 30, 2024, compared with the year-ago period, primarily due to increased fuel and purchased power expenses at Ameren Missouri, partially offset by decreased fuel and purchased power expenses at Ameren Illinois Electric Distribution, as discussed below. Ameren’s electric fuel and purchased power expenses decreased $364 million, or 24%, for the nine months ended September 30, 2024, compared with the year-ago period, primarily due to decreased fuel and purchased power expenses at Ameren Illinois Electric Distribution and Ameren Missouri, as discussed below.
Ameren Missouri
Ameren Missouri’s fuel and purchased power expenses increased $101 million, or 43%, for the three months ended September 30, 2024, and decreased $154 million, or 18%, for the nine months ended September 30, 2024, compared with the year-ago periods.
The following items decreased Ameren Missouri’s fuel and purchased power expense for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•Energy costs decreased $130 million for the nine months ended September 30, 2024, primarily due to lower winter and spring capacity prices, partially offset by higher summer capacity prices, which were set by annual MISO auctions. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC is included within “Energy costs (excluding the estimated effect of weather)” and “Off-system sales, capacity, and FAC revenues, net” in electric revenues.
•“Cost recovery mechanisms — offset in electric revenue” decreased $11 million and $49 million, respectively, due to decreased amortization of costs previously deferred under the FAC. The changes to “Cost recovery mechanisms - offset in electric revenue” are fully offset by “Cost recovery mechanisms - offset in fuel and purchased power” in electric revenues.
The following items increased Ameren Missouri’s fuel and purchased power expense for the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
•Energy costs increased $113 million for the three months ended September 30, 2024, primarily due to higher summer capacity prices, which were set by annual MISO auctions. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC is included within “Energy costs (excluding the estimated effect of weather)” and “Off-system sales, capacity, and FAC revenues, net” in electric revenues.
•The effect of higher net energy costs included in base rates increased Ameren Missouri’s fuel and purchased power expenses $22 million for the nine months ended September 30, 2024, as a result of the June 2023 MoPSC electric rate order.
Ameren Illinois Electric Distribution
Ameren Illinois Electric Distribution’s purchased power expenses decreased $29 million, or 12%, and $202 million, or 26%, for the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, primarily due to decreased energy prices (-$5 million and -$83 million, respectively), which largely reflect the results of IPA procurement events, decreased capacity prices (-$8 million and -$67 million, respectively), which were set by annual MISO auctions, and lower volumes (-$14 million and -$51 million, respectively) primarily due to residential and small commercial customers switching from Ameren Illinois’ supplied power to alternative retail electric suppliers and customer adoption of solar technology through initiatives required under Illinois law. The changes to “Cost recovery mechanisms - offset in electric revenue” are fully offset by changes to “Cost recovery mechanisms - offset in fuel and purchased power” in electric revenues.
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Natural Gas Purchased for Resale
The following table presents the increases (decreases) by Ameren segment for natural gas purchased for resale for the three and nine months ended September 30, 2024, compared with the year-ago periods:

Three Months | Ameren Missouri |  | Ameren Illinois Electric Distribution |  | Ameren Illinois Natural Gas |  | Ameren Transmission |  | Other /Intersegment Eliminations |  | Ameren |  |  |  |  |
Natural gas purchased for resale change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Effect of weather (estimate)(a) | $ | (1) |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | (1) |  |  |  |  |  |
Cost recovery mechanisms – offset in natural gas revenue(b) | 1 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  |  |  |  |
Total natural gas purchased for resale change | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  |  |  |  |
Nine Months |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Natural gas purchased for resale change: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Effect of weather (estimate)(a) | $ | 1 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 1 |  |  |  |  |  |
Cost recovery mechanisms – offset in natural gas revenue(b) | (20) |  |  | — |  |  | (47) |  |  | — |  |  | — |  |  | (67) |  |  |  |  |  |
Total natural gas purchased for resale change | $ | (19) |  |  | $ | — |  |  | $ | (47) |  |  | $ | — |  |  | $ | — |  |  | $ | (66) |  |  |  |  |  |

(a)Represents the estimated variation resulting primarily from changes in cooling and heating degree-days on natural gas demand compared with the year-ago periods; this variation is based on temperature readings from the National Oceanic and Atmospheric Administration weather stations at local airports in our service territories.
(b)Natural gas purchased for resale changes are offset by corresponding changes in “Natural gas revenues” on the statement of income. These items have no overall impact on earnings.
Ameren
Ameren Missouri and Ameren Illinois are allowed to pass on to customers prudently incurred costs for natural gas purchased for resale. Ameren’s natural gas purchased for resale expenses were comparable for the three months ended September 30, 2024, and decreased $66 million, or 24%, for the nine months ended September 30, 2024, compared with the year-ago periods, due to decreased natural gas purchased for resale expenses at Ameren Illinois Natural Gas and Ameren Missouri, as discussed below.
Ameren Missouri
Ameren Missouri’s natural gas purchased for resale expenses were comparable for the three months ended September 30, 2024, and decreased $19 million, or 32%, for the nine months ended September 30, 2024, compared with the year-ago periods. Expenses associated with “Cost recovery mechanisms – offset in natural gas revenue” decreased $20 million for the nine months ended September 30, 2024, due to lower commodity prices and the absence of amortization of natural gas costs deferred under the PGA related to the extremely cold weather in mid-February 2 021. Changes in natural gas purchased for resale expenses are fully offset by corresponding changes in natural gas revenues under the PGA.
Ameren Illinois Natural Gas
Ameren Illinois Natural Gas’ natural gas purchased for resale expenses were comparable for the three months ended September 30, 2024, and decreased $47 million, or 21%, for the nine months ended September 30, 2024, compared with the year-ago periods, primarily due to lower amortization of natural gas costs that were previously deferred under the PGA and lower natural gas prices. Changes in natural gas purchased for resale expenses are fully offset by changes in natural gas revenues under the PGA.
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Other Operations and Maintenance Expenses

|  |  | Increase (Decrease) by Segment |
|  |  | Overall Ameren Increase of $50 Million (QTD YoY) |  | Overall Ameren Increase of $87 Million (YTD YoY) |
| Total by Segment(a) |  |  |

(a)Includes $19 million and $15 million at Ameren Transmission in the three months ended September 30, 2024 and 2023, respectively. Includes other/intersegment eliminations of $(1) million and $11 million in the three months ended September 30, 2024 and 2023, respectively. Also includes other/intersegment eliminations of $(8) million and $25 million in the nine months ended September 30, 2024 and 2023, respectively.

|  | Ameren Missouri |  |  | Ameren Illinois Natural Gas |  |  | Other/Intersegment Eliminations
|  | Ameren Illinois Electric Distribution |  | Ameren Transmission |  |  |  |

Ameren
Other operations and maintenance expenses increased $50 million and $87 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, because of the changes discussed below. In addition to changes by segments discussed below, other operations and maintenance expenses decreased $12 million and $33 million in the three and nine months ended September 30, 2024, respectively, for activity not reported as part of a segment, as reflected in “Other/Intersegment Eliminations” above, primarily because of an increase in the elimination of intercompany rent related to ATXI’s operations control center discussed below of $5 million and $10 million, respectively; a $9 million gain on the sale of land in the nine months ended September 30, 2024; and an increase in the elimination of the non-service cost component of net periodic benefit income at Ameren Services of $3 million and $8 million, respectively. The non-service cost component of net periodic benefit cost or income at Ameren Services is allocated to the segments and primarily included in the segments’ other operations and maintenance expenses.
Ameren Transmission
Other operations and maintenance expenses increased $4 million and $10 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, primarily because of increased costs related to ATXI’s operations control center, which was placed in service in December 2023. ATXI provides affiliates with access to this facility. The rent expense associated with this facility is an affiliate transaction and eliminated in consolidation for purposes of Ameren’s consolidated financial statements. See Note 8 – Related-party Transactions under Part I, Item 1, of this report for additional information.
Ameren Missouri
Other operations and maintenance expenses increased $32 million and $57 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods. The following items increased other operations and maintenance expenses in the three and nine months ended September 30, 2024, compared with the year-ago periods (except where a specific period is referenced):
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•A $44 million and $59 million charge, respectively, related to an agreement in principle with the United States Department of Justice, which, if approved, would resolve all outstanding claims in the NSR and Clean Air Act litigation related to the Rush Island Energy Center, see Note 9 - Commitments and Contingencies under Part 1, Item 1, of this report for more information.
•The absence in 2024 of the recognition of regulatory assets for previously expensed costs approved for recovery pursuant to the June 2023 MoPSC rate order increased expenses $15 million for the nine months ended September 30, 2024.
•Individually insignificant increases of $2 million and $8 million, respectively, in various other operations and maintenance expenses, including other labor, cloud computing costs, and amortization of regulatory assets associated with previously expensed costs approved for recovery pursuant to the June 2023 MoPSC rate order.
•Legal and administrative expenses increased by $5 million, in the nine months ended September 30, 2024, primarily related to environmental matters.
•The absence of previously deferred expenses increased expense by $4 million in the three months ended September 30, 2024.
•Renewable development costs increased $3 million in the nine months ended September 30, 2024, primarily due to the absence in 2024 of the MoPSC order approving CCNs for the Boomtown and Huck Finn solar projects in the first half of 2023 that led to increased capitalization of renewable development costs pursuant to anticipated recovery from customers.
•Costs for injuries and damages increased $3 million in the three months ended September 30, 2024, primarily due to an increase in claims.
The above increases in the three and nine months ended September 30, 2024, compared with the year-ago periods, were partially offset by the following items (except where a specific period is referenced):
•Pension and benefit costs decreased $21 million in the nine months ended September 30, 2024, because of a lower base level of expenses, subject to a tracker, included in customer rates pursuant to the June 2023 MoPSC electric rate order. See Note 11 - Retirement Benefits under Part 1, Item 1 of this report for more information.
•Energy center maintenance decreased $3 million and $12 million, respectively, primarily because of lower amortization of Callaway Energy Center refueling and maintenance costs resulting from cost saving initiatives in the fall 2023 outage, compared to the spring 2022 outage.
•Transmission and distribution storm-related costs decreased $11 million in the three months ended September 30, 2024, because of the major storms experienced throughout the service territory in July and August 2023.
•The cash surrender value of COLI increased $7 million and $5 million, respectively, primarily because of favorable market returns in 2024 compared with unfavorable market returns in 2023.
Ameren Illinois
Other operations and maintenance expenses increased $29 million and $60 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, as discussed below.
Ameren Illinois Electric Distribution
Other operations and maintenance increased $31 million and $58 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods primarily due to the following items:
•Bad debt costs increased $19 million and $35 million, respectively, primarily because of a higher base level of expenses included in customer rates pursuant to the associated rider.
•Amortization of previous deferrals associated with bad debt costs on purchased receivables increased $5 million and $10 million, respectively, primarily because of a higher base level of expenses included in customer rates pursuant to the associated rider.
•Increased costs associated with customer energy-efficiency investments under formula ratemaking of $2 million and $8 million, respectively, primarily due to amortization of regulatory assets.
•Pension and benefits costs increased $6 million in both periods, primarily due to an increase in medical benefit claims related to active plan participants.
•Increased labor expense of $2 million a nd $5 million, respectively, primarily caused by reduced capital expenditures due to steps taken to align 2024 operations under the MYRP order, resulting in more maintenance activities.
•Costs for injuries and damages increased $2 million and $3 million, respectively, primarily because of an increase in claims.
•Absence of major storm-related cost deferrals in 2024 increased expense by $3 million in the nine months ended September 30, 2024.
•Vegetation management costs increased by $3 million in the nine months ended September 30, 2024, due to increased maintenance activity.
The above increases in the three and nine months ended September 30, 2024, compared with the year-ago periods, were partially offset by the following items:
•Reduction in environmental remediation rider costs of $4 million and $12 million, respectively.
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•The cash surrender value of company-owned life insurance increased $3 million in both periods, primarily because of favorable market returns in 2024 when compared with unfavorable market returns in 2023.
Ameren Illinois Natural Gas
Other operations and maintenance costs decreased $5 million in the three and nine months ended September 30, 2024, compared with the year-ago periods, primarily due to a decrease of $4 million in contractor service costs and a $2 million decrease in labor expense due to steps taken to align operations and maintenance expense as a result of the November 2023 ICC natural gas rate order. These decreases were partially offset by an increase of $2 million in cloud computing costs.
Ameren Illinois Transmission
Other operations and maintenance expenses increased $3 million and $7 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, primarily because of increased costs related to ATXI’s operations control center, which was placed in service in December 2023. ATXI provides affiliates with access to this facility. The rent expense associated with this facility is an affiliate transaction and eliminated in consolidation for purposes of Ameren’s consolidated financial statements. See Note 8 – Related-party Transactions under Part I, Item 1, of this report for additional information.
Depreciation and Amortization Expenses

|  |  | Increase by Segment |
|  |  | Overall Ameren Increase of $19 Million (QTD YoY) |  | Overall Ameren Increase of $101 Million (YTD YoY) |
| Total by Segment(a) |  |  |

(a)Includes other/intersegment eliminations of $2 million and $3 million in the three months ended September 30, 2024 and 2023, respectively. Also includes other/intersegment eliminations of $5 million and $5 million in the nine months ended September 30, 2024 and 2023, respectively.

|  | Ameren Missouri |  |  | Ameren Illinois Natural Gas |  |  | Other/Intersegment Eliminations
|  | Ameren Illinois Electric Distribution |  | Ameren Transmission |  |  |  |

Depreciation and amortization expenses increased $19 million, $16 million, and $3 million in the three months ended September 30, 2024, and $101 million, $52 million, and $44 million in the nine months ended September 30, 2024, compared with the year-ago periods, at Ameren, Ameren Illinois, and Ameren Missouri respectively, primarily because of additional property, plant, and equipment investments across their respective segments. Ameren’s and Ameren Missouri’s depreciation and amortization expenses for the three and nine months ended September 30, 2024, compared with the year-ago periods, were affected by the following, which include the effect of the additional investments at Ameren Missouri:
•Increased depreciation and amortization of $40 million in the nine months ended September 30, 2024, due to the inclusion in base rates
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of amounts previously deferred under the PISA and RESRAM effective July 9, 2023, pursuant to the June 2023 MoPSC electric rate order.
•The lower net under-recovery of RESRAM eligible expenses and increased amortization of prior deferrals increased depreciation and amortization expenses by $10 million and $28 million, respectively.
•Depreciation and amortization rate changes pursuant to the electric rate orders noted above, which increased depreciation and amortization expenses by $4 million in the nine months ended September 30, 2024.
•Depreciation and amortization expenses reflected a deferral to a regulatory asset of depreciation associated with investments in eligible property, plant, and equipment not yet included in base rates, pursuant to PISA and RESRAM. Base rates were updated to include the eligible property, plant, and equipment in-service through December 31, 2022, when new customer rates became effective on July 9, 2023, pursuant to the June 2023 MoPSC electric rate order. The effect of rebasing PISA and RESRAM, partially offset by increased amortization of prior PISA deferrals in the nine months ended September 30, 2024, decreased depreciation and amortization by $4 million and $20 million, respectively.
•The higher net deferral pursuant to a tracker related to certain excess deferred income taxes, which decreased depreciation and amortization expenses by $4 million and $8 million, respectively.
Taxes Other Than Income Taxes

|  |  | Increase by Segment |
|  |  | Overall Ameren Increase of $3 Million (QTD YoY) |  | Overall Ameren Increase of $18 Million (YTD YoY) |
| Total by Segment(a) |  |  |

(a)Includes $2 million, $2 million, $6 million, and $6 million at Ameren Transmission in the three months ended September 30, 2024 and 2023, and in the nine months ended September 30, 2024 and 2023, respectively. Also includes other/intersegment eliminations of $4 million, $4 million, $11 million, and $11 million in the three months ended September 30, 2024 and 2023, and in the nine months ended September 30, 2024 and 2023, respectively.

|  | Ameren Missouri |  |  | Ameren Illinois Natural Gas |  |  | Other/Intersegment Eliminations
|  | Ameren Illinois Electric Distribution |  | Ameren Transmission |  |  |  |

Taxes other than income taxes increased $3 million in the three months ended September 30, 2024, compared with the year-ago period, primarily because of an increase of $2 million at Ameren Illinois Natural Gas due to an increase in excise taxes resulting from higher invested capital taxes.
Taxes other than income taxes increased $18 million in the nine months ended September 30, 2024, compared with the year-ago period, primarily because of an increase of $7 million and $2 million at Ameren Missouri and Ameren Illinois Electric Distribution, respectively, because of the absence in 2024 of employee retention tax credits received under the Coronavirus Aid, Relief, and Economic Security Act; an increase of $6 million at Ameren Illinois Natural Gas due to an increase in excise taxes resulting from higher invested capital taxes; and an increase of $2 million in gross receipts taxes at Ameren Missouri, primarily due to increased retail electric sales.
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Other Income, Net

|  |  | Increase (Decrease) by Segment |
|  |  | Overall Ameren Change of $— Million (QTD YoY) |  | Overall Ameren Increase of $32 Million (YTD YoY) |
| Total by Segment(a) |  |  |

(a)Includes $8 million and $7 million at Ameren Transmission in the three months ended September 30, 2024 and 2023, respectively.

|  | Ameren Missouri |  |  | Ameren Illinois Natural Gas |  |  | Other/Intersegment Eliminations
|  | Ameren Illinois Electric Distribution |  | Ameren Transmission |  |  |  |

See Note 5 – Other Income, Net, under Part I, Item 1, of this report for additional information. See Note 11 – Retirement Benefits under Part I, Item 1, of this report for more information on the non-service cost components of net periodic benefit income.
Ameren
Other income, net, was comparable in the three months ended September 30, 2024. Other income, net, increased $32 million in the nine months ended September 30, 2024. In addition to changes discussed below, other income, net, decreased $3 million and $10 million, respectively, because of increases in the non-service cost component of net periodic benefit income for activity not reported as part of a segment.
Ameren Transmission
Other income, net, was comparable in the three months ended September 30, 2024. Other income, net, decreased $7 million in the nine months ended September 30, 2024, due to lower allowance for equity funds used during construction, primarily related to lower average construction work in progress balances and an increased level of short-term borrowings included in the calculation.
Ameren Missouri
Other income, net, increased $7 million and $59 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, primarily because of an increase of $42 million in the nine months ended September 30, 2024, in the non-service cost component of net periodic benefit income because of changes in the base level of pension and postretirement costs pursuant to the June 2023 MoPSC electric rate order. Other income, net, also increased $7 million and $18 million, respectively, because of a higher allowance for equity funds used during construction resulting from higher average construction work in progress balances.
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Ameren Illinois
Other income, net, was comparable at Ameren Illinois in the three months ended September 30, 2024. Other income, net, decreased $10 million in the nine months ended September 30, 2024, compared with the year-ago period, primarily because of a decrease of $9 million and $4 million in the non-service cost component of net periodic benefit income at Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively. Other income, net decreased $5 million in the allowance of equity funds used during construction, largely at Ameren Illinois Transmission. These decreases were partially offset by the increase in other interest income on regulatory balances of $8 million at Ameren Illinois Electric Distribution.
Interest Charges

|  |  | Increase by Segment |
|  |  | Overall Ameren Increase of $21 Million (QTD YoY) |  | Overall Ameren Increase of $79 Million (YTD YoY) |
| Total by Segment |  |  |

|  | Ameren Missouri |  |  | Ameren Illinois Natural Gas |  |  | Other/Intersegment Eliminations
|  | Ameren Illinois Electric Distribution |  | Ameren Transmission |  |  |  |

See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and the Long-term Debt and Equity section below for additional information on short-term borrowings and long-term debt, respectively, discussed below.
Ameren
Interest charges increased $21 million and $79 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods. In addition to changes by segments discussed below, interest charges increased $13 million and $27 million, respectively, compared with the year-ago periods, at Ameren (parent) primarily because of issuances of long-term debt in November and December of 2023, which collectively increased interest charges by $17 million and $52 million, respectively. The net proceeds from these issuances were used to repay short-term borrowings, which decreased short-term interest expense by $4 million and $25 million, respectively, compared with the year-ago periods.
Ameren Transmission
Interest charges increased $6 million and $19 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, because of an increase of $2 million in the nine months ended September 30, 2024 due to increased levels of intercompany borrowings and an increase of $3 million and $7 million, respectively, due to higher long-term debt balances. Additionally, an increase on long-term debt and a higher interest rate on an increased level of short-term borrowings increased interest charges by $3 million and $3 million, respectively, in the nine months ended September 30, 2024.
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Ameren Missouri
Interest charges decreased $1 million and increased $21 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods because of the following items:
•Issuances of long-term debt in March 2023, January 2024, and April 2024, which collectively increased interest charges by $11 million and $32 million, respectively.
•Interest charges reflected a deferral to a regulatory asset of interest associated with investments in eligible property, plant, and equipment not yet included in base rates, pursuant to PISA and RESRAM. Base rates were updated to include the eligible property, plant, and equipment in-service through December 31, 2022, when new customer rates became effective on July 9, 2023, pursuant to the June 2023 MoPSC electric rate order. This update to base rates resulted in a lower deferral of interest in 2024 pursuant to PISA and RESRAM that increased interest charges by $3 million in the nine months ended September 30, 2024.
•Higher level of short-term borrowings increased interest charges by $2 million in the three months ended September 30, 2024.
The above increases in the three and nine months ended September 30, 2024, compared with the year-ago periods, were partially offset by the following items:
•Increase in the borrowed funds capitalized as part of the allowance for funds used during construction of $4 million and $7 million, respectively, primarily due to higher average construction work in progress balances.
•Lower level of short-term borrowings decreased interest charges by $4 million in the nine months ended September 30, 2024.
•Interest charges reflected a deferral to a regulatory asset of interest associated with investments in eligible property, plant, and equipment not yet included in base rates, pursuant to PISA and RESRAM. Base rates were updated to include the eligible property, plant, and equipment in-service through December 31, 2022, when new customer rates became effective on July 9, 2023, pursuant to the June 2023 MoPSC electric rate order. This update to base rates resulted in a higher deferral of interest in 2024 pursuant to PISA and RESRAM that decreased interest charges by $6 million in the three months ended September 30, 2024.
Ameren Illinois
Interest charges increased $9 million and $27 million in the three and nine months ended September 30, 2024, respectively, compared with the year-ago periods, primarily because of the following:
Ameren Illinois Transmission
Interest charges increased by $6 million and $15 million, respectively, primarily because of issuances of long-term debt in May 2023 and June 2024 which increased interest charges by $3 million and $7 million, respectively. Additionally, an increase interest on long-term debt and a higher interest rate on an increased level of short-term borrowings increased interest charges by $3 million and $2 million, respectively, in the nine months ended September 30, 2024.
Ameren Illinois Electric Distribution
Interest charges increased by $2 million and $7 million, respectively, primarily because of issuances of long-term debt in May 2023 and June 2024.
Ameren Illinois Natural Gas
Interest charges increased by $1 million and $5 million, respectively, primarily because of issuances of long-term debt in May 2023 and June 2024.
Income Taxes
The following table presents effective income tax rates for the three and nine months ended September 30, 2024 and 2023:

|  | Three Months(a) |  | Nine Months(a)
|  | 2024 |  | 2023 |  | 2024 |  | 2023
Ameren |  | 11 | % |  | 12 | % |  | 13 | % |  | 13 | %
Ameren Missouri |  | (2) | % |  | (3) | % |  | (1) | % |  | (3) | %
Ameren Illinois |  | 24 | % |  | 25 | % |  | 24 | % |  | 25 | %
Ameren Illinois Electric Distribution |  | 20 | % |  | 21 | % |  | 19 | % |  | 24 | %
Ameren Illinois Natural Gas |  | 22 | % |  | (b) |  | 27 | % |  | 27 | %
Ameren Illinois Transmission |  | 27 | % |  | 27 | % |  | 27 | % |  | 26 | %
Ameren Transmission |  | 27 | % |  | 27 | % |  | 27 | % |  | 26 | %

(a)Estimate of the annual effective income tax rate adjusted to reflect the tax effect of items discrete to the three and nine months ended September 30, 2024 and 2023.
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(b)Not meaningful because of the insignificant amount of income/(loss) before income taxes.
See Note 12 – Income Taxes under Part I, Item 1, of this report for a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the Ameren Companies.
The effective tax rate was lower at Ameren Illinois Electric Distribution in the three and nine months ended September 30, 2024, compared with the year-ago periods, primarily because of an increase in excess deferred tax amortization pursuant to an ICC order, which was offset by a corresponding decrease in revenues.
LIQUIDITY AND CAPITAL RESOURCES
Collections from our tariff-based revenues are our principal source of cash provided by operating activities. A diversified retail customer mix, primarily consisting of rate-regulated residential, commercial, and industrial customers, provides us with a reasonably predictable source of cash. In addition to using cash provided by operating activities, we use available cash, drawings under committed credit agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings to support normal operations and temporary capital requirements. We may reduce our short-term borrowings with cash provided by operations or, at our discretion, with long-term borrowings, or, in the case of Ameren Missouri and Ameren Illinois, with capital contributions from Ameren (parent). As of September 30, 2024, there have been no material changes other than in the ordinary course of business related to cash requirements arising from the long-term commitments for fuel for generation, purchased power, and natural gas for distribution as described under Liquidity and Capital Resources in Item 7 of the Form 10-K.
We expect to make significant capital expenditures over the next five years, supported by a combination of long-term debt and equity, as we invest in our electric and natural gas utility infrastructure to support overall system reliability, grid modernization, renewable energy target requirements, environmental compliance, and other improvements. For additional information about our long-term debt outstanding, including maturities due within one year, and the applicable interest rates, see Note 5 – Long-term Debt and Equity Financings under Part II, Item 8 of the Form 10-K and Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report. As part of its funding plan for capital expenditures, Ameren is using newly-issued shares of common stock to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 2028. Additionally, Ameren has an ATM program under which Ameren may offer and sell from time to time common stock, which includes the ability to enter into forward sales agreements, subject to market conditions and other factors. There were no shares issued under the ATM program during the nine months ended September 30, 2024. As of September 30, 2024, Ameren had multiple forward sale agreements that could be settled under the ATM program with various counterparties relating to 4.7 million shares of common stock. Ameren expects to settle approximately $230 million of the forward sale agreements with physical delivery of 2.9 million shares of common stock by December 31, 2024. Including issuances under the DRPlus and employee benefit plans, Ameren plans to issue approximately $300 million of equity in 2024 and approximately $600 million of equity each year from 2025 to 2028. As of September 30, 2024, Ameren had approximately $615 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of September 30, 2024. The Ameren Companies expect their equity to total capitalization to support solid investment-grade credit ratings. See Long-term Debt and Equity below and Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for additional information on the ATM program, including the forward sale agreements under the ATM program relating to common stock.
The following table presents net cash provided by (used in) operating, investing, and financing activities for the nine months ended September 30, 2024 and 2023:

| Net Cash Provided By Operating Activities |  | Net Cash Used In Investing Activities |  | Net Cash Provided By Financing Activities
| 2024 |  | 2023 |  | Variance |  | 2024 |  | 2023 |  | Variance |  | 2024 |  | 2023 |  | Variance
Ameren | $ | 1,946 |  | (a) | $ | 2,031 |  | (a) | $ | (85) |  |  | $ | (3,106) |  |  | $ | (2,656) |  |  | $ | (450) |  |  | $ | 1,212 |  |  | $ | 655 |  |  | $ | 557 |
Ameren Missouri | 997 |  |  | 1,031 |  |  | (34) |  |  | (1,932) |  |  | (1,338) |  |  | (594) |  |  | 935 |  |  | 307 |  |  | 628 |
Ameren Illinois | 1,067 |  | (a) | 1,026 |  | (a) | 41 |  |  | (1,090) |  |  | (1,229) |  |  | 139 |  |  | 82 |  |  | 237 |  |  | (155) |

(a)Both Ameren and Ameren Illinois’ cash provided by operating activities included cash outflows of $82 million and $84 million for the FEJA electric energy-efficiency rider and $20 million and $6 million for the customer generation rebate program for the nine months ended September 30, 2024 and 2023, respectively.
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Cash Flows from Operating Activities
Our cash provided by operating activities is affected by fluctuations of trade accounts receivable, inventories, and accounts and wages payable, among other things, as well as the unique regulatory environment for each of our businesses. Substantially all expenditures related to fuel, purchased power, and natural gas purchased for resale are recovered from customers through rate adjustment mechanisms, which may be adjusted without a traditional regulatory rate review, subject to prudence reviews. Similar regulatory mechanisms exist for certain other operating expenses that can also affect the timing of cash provided by operating activities. The timing of cash payments for costs recoverable under our regulatory mechanisms differs from the recovery period of those costs. Additionally, the seasonality of our electric and natural gas businesses, primarily caused by seasonal customer rates and changes in customer demand due to weather, significantly affects the amount and timing of our cash provided by operating activities.
Ameren
Ameren’s cash provided by operating activities decreased $85 million in the first nine months of 2024, compared with the year-ago period. The following items contributed to the decrease:
•A $143 million increase in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.
•A $46 million decrease due to the timing of payments for accounts payable.
•A $45 million increase in interest payments, primarily due to an increase in the average outstanding debt and an increase in interest rates.
•A $29 million increase in the cost of natural gas held in storage, primarily at Ameren Illinois, because of higher volumes, partially offset by lower commodity prices.
•A $10 million increase in payroll taxes, primarily at Ameren Missouri, due to the absence of employee retention tax credits received in the year-ago period under the Coronavirus Aid, Relief, and Economic Security Act.
•A $10 million increase in medical benefit costs.
•A $6 million increase in pension and postretirement benefit plan contributions.
The following items partially offset the decrease in Ameren’s cash from operating activities between periods:
•A $90 million increase resulting from increased customer collections primarily from base rate increases effective July 1, 2023, at Ameren Missouri pursuant to the June 2023 electric rate order and base rate increases effective November 28, 2023, at Ameren Illinois pursuant to the November 2023 natural gas rate order and electric transmission rate base growth, partially offset by lower customer collections under cost recovery mechanisms at Ameren Missouri.
•A $37 million increase due to the transfer of production tax credits generated by the High Prairie Renewable and Atchison Renewable energy centers to unrelated third parties and lower income tax payments primarily due to lower taxable income compared to the year-ago period.
•A $34 million increase due to higher purchases of materials and supplies inventories in the year-ago period to support operations as levels were increased to mitigate against potential supply disruptions.
•A $22 million increase due to insurance proceeds received in 2024 related to workers’ compensation payments made in the year-ago period at Ameren Illinois.
•A $19 million increase due to workers’ compensation payments made in the year-ago period at Ameren Illinois.
•An $18 million increase due to higher coal purchases in the year-ago period to bring coal inventories back to targeted levels after transportation delays experienced in 2022.
Ameren Missouri
Ameren Missouri’s cash provided by operating activities decreased $34 million in the first nine months of 2024, compared with the year-ago period. The following items contributed to the decrease:
•A $92 million increase in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.
•A $42 million decrease due to the timing of payments for accounts payable and prepaid expenses.
•A $15 million increase in interest payments, primarily due to an increase in the average outstanding debt and an increase in interest rates.
•A $7 million increase in payroll taxes due to the absence of employee retention tax credits received in the year-ago period under the Coronavirus Aid, Relief, and Economic Security Act.
The following items partially offset the decrease in Ameren Missouri’s cash from operating activities between periods:
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•A $61 million increase due to the transfer of production tax credits generated by the High Prairie Renewable and Atchison Renewable energy centers to unrelated parties, as well as an income tax refund from Ameren (parent), pursuant to the tax allocation agreement, primarily due to lower taxable income compared to the year-ago period.
•A $32 million increase due to higher purchases of materials and supplies inventories in the year-ago period to support operations as levels were increased to mitigate against potential supply disruptions.
•A $21 million increase resulting from increased customer collections primarily from base rate increases effective July 1, 2023, pursuant to the June 2023 electric rate order, partially offset by lower customer collections under cost recovery mechanisms.
•An $18 million increase due to higher coal purchases in the year-ago period to bring coal inventories back to targeted levels after transportation delays experienced in 2022.
Ameren Illinois
Ameren Illinois’ cash provided by operating activities increased $41 million in the first nine months of 2024, compared with the year-ago period. The following items contributed to the increase:
•A $57 million increase resulting from increased customer collections primarily from base rate increases effective November 28, 2023, pursuant to the November 2023 natural gas rate order and electric transmission rate base growth, and by increased customer collections under cost recovery mechanisms.
•A $52 million increase due to lower income tax payments to Ameren (parent), pursuant to the tax allocation agreement, primarily due to lower taxable income compared to the year-ago period.
•A $22 million increase due to insurance proceeds received in 2024 related to workers’ compensation payments made in the year-ago period.
•A $19 million increase due to workers’ compensation payments made in the year-ago period.
The following items partially offset the increase in Ameren Illinois’ cash from operating activities between periods:
•A $42 million increase in net collateral posted with counterparties, primarily due to changes in the market prices of power and natural gas.
•A $25 million increase in the cost of natural gas held in storage because of higher volumes, partially offset by lower commodity prices.
•A $21 million decrease due to the timing of payments for accounts payable.
•An $18 million increase in interest payments, primarily due to an increase in the average outstanding debt and an increase in interest rates.
Cash Flows from Investing Activities
Ameren’s cash used in investing activities increased $450 million during the first nine months of 2024, compared with the year-ago period, primarily as a result of a $458 million increase in capital expenditures, largely resulting from the acquisition of the Cass County and Boomtown solar projects at Ameren Missouri, partially offset by decreased expenditures for electric transmission infrastructure upgrades at Ameren Illinois. Ameren’s increase in capital expenditures was also partially offset by decreased expenditures for electric distribution infrastructure upgrades and natural gas infrastructure at Ameren Illinois due to steps taken by Ameren Illinois to align its 2024 operations with the ICC’s MYRP orders and November 2023 natural gas rate order.
Ameren Missouri’s cash used in investing activities increased $594 million during the first nine months of 2024, compared with the year-ago period, primarily as a result of a $584 million increase in capital expenditures, largely resulting from the acquisition of the Cass County and Boomtown solar projects.
Ameren Illinois’ cash used in investing activities decreased $139 million during the first nine months of 2024, compared with the year-ago period, primarily as a result of a $135 million decrease in capital expenditures, largely resulting from decreased expenditures for electric transmission infrastructure upgrades. Ameren Illinois’ capital expenditures also decreased as a result of reduced expenditures for electric distribution infrastructure upgrades and natural gas infrastructure due to steps taken by Ameren Illinois to align its 2024 operations with the ICC’s MYRP orders and November 2023 natural gas rate order.
Cash Flows from Financing Activities
Cash provided by, or used in, financing activities is a result of our financing needs, which depend on the level of cash provided by operating activities, the level of cash used in investing activities, the level of dividends, and our long-term debt maturities, among other things.
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Ameren’s cash provided by consolidated financing activities increased $557 million during the first nine months of 2024, compared with the year-ago period. During the first nine months of 2024, Ameren utilized net proceeds from the issuance of long-term debt of $1.6 billion for capital expenditures, to repay then-outstanding short-term debt, and to repay $49 million of maturities of long-term debt at ATXI. During the first nine months of 2024, Ameren utilized proceeds from net commercial paper issuances of $1.0 billion along with cash on hand and cash provided by operating activities to repay $800 million of long-term debt maturities at Ameren (parent) and Ameren Missouri, and to fund, in part, capital expenditures. In comparison, during the first nine months of 2023, Ameren utilized net proceeds from the issuance of long-term debt of $1.0 billion for capital expenditures, to repay then-outstanding short-term debt, and to repay $100 million of long-term debt maturities. In addition, during the first nine months of 2023, Ameren utilized proceeds from net commercial paper issuances of $272 million along with cash provided by operating activities to fund, in part, capital expenditures. During the first nine months of 2024, Ameren paid common stock dividends of $535 million, compared with $496 million in the year-ago period, as a result of an increase in both the dividend rate and the number of common shares outstanding.
Ameren Missouri’s cash provided by financing activities increased $628 million during the first nine months of 2024, compared with the year-ago period. During the first nine months of 2024, Ameren Missouri utilized net proceeds from the issuance of long-term debt of $846 million for capital expenditures and to repay then-outstanding short-term debt. During the first nine months of 2024, Ameren Missouri utilized net commercial paper issuances totaling $406 million, capital contributions from Ameren (parent) of $350 million, and cash provided by operating activities to fund, in part, capital expenditures. Ameren Missouri also repaid $350 million of long-term debt maturities and $289 million of money pool borrowings during the first nine months of 2024. In comparison, during the first nine months of 2023, Ameren Missouri utilized net proceeds from the issuance of long-term debt of $499 million for capital expenditures and to repay then-outstanding short-term debt. During the first nine months of 2023, Ameren Missouri repaid net commercial paper borrowings totaling $172 million.
Ameren Illinois’ cash provided by financing activities decreased $155 million during the first nine months of 2024, compared with the year-ago period. During the first nine months of 2024, Ameren Illinois utilized proceeds from the issuance of long-term debt of $624 million to repay then-outstanding short-term debt. In addition, during the first nine months of 2024, Ameren Illinois repaid net commercial paper borrowings of $349 million and money pool borrowings of $135 million. In comparison, during the first nine months of 2023, Ameren Illinois utilized net proceeds from the issuance of long-term debt of $498 million to repay then-outstanding short-term debt and $100 million of long-term debt maturities. In addition, during the first nine months of 2023, Ameren Illinois repaid net commercial paper borrowings totaling $205 million and also received a $50 million capital contribution from Ameren (parent). During the first nine months of 2024, Ameren Illinois also paid common stock dividends of $50 million.
See Long-term Debt and Equity in this section for additional information on maturities and issuances of long-term debt, issuances of common stock, and noncash settlement of a financing obligation.
Credit Facility Borrowings and Liquidity
The following table presents Ameren’s consolidated liquidity as of September 30, 2024:

|  |  |  |  | Available at September 30, 2024
Ameren (parent) and Ameren Missouri: |  |  |  |  |
Missouri Credit Agreement – borrowing capacity |  |  |  |  | $ | 1,400 |
Less: Ameren (parent) commercial paper outstanding |  |  |  |  | 557 |
Less: Ameren Missouri commercial paper outstanding |  |  |  |  | 576 |
Less: Letters of credit |  |  |  |  | 17 |
Missouri Credit Agreement – subtotal |  |  |  |  | 250 |
Ameren (parent) and Ameren Illinois: |  |  |  |  |
Illinois Credit Agreement – borrowing capacity |  |  |  |  | 1,200 |
Less: Ameren (parent) commercial paper outstanding |  |  |  |  | 389 |
Less: Ameren Illinois commercial paper outstanding |  |  |  |  | 17 |
Less: Ameren Illinois letters of credit |  |  |  |  | 1 |
Illinois Credit Agreement – subtotal |  |  |  |  | 793 |
Subtotal |  |  |  |  | $ | 1,043 |
Add: Cash and cash equivalents |  |  |  |  | 17 |
Net Available Liquidity(a) |  |  |  |  | $ | 1,060 |

(a)Does not include Ameren’s forward equity sale agreements. See Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for additional information.
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The Credit Agreements, among other things, provide $2.6 billion of credit until maturity in December 2027. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on the Credit Agreements. During the nine months ended September 30, 2024, Ameren (parent), Ameren Missouri, and Ameren Illinois each issued commercial paper. Borrowings under the Credit Agreements and commercial paper issuances are based upon available interest rates at the time of the borrowing or issuance.
Ameren has a money pool agreement with and among its utility subsidiaries to coordinate and to provide for certain short-term cash and working capital requirements. As short-term capital needs arise, and based on availability of funding sources, Ameren Missouri and Ameren Illinois will access funds from the utility money pool, the Credit Agreements, or the commercial paper programs depending on which option has the lowest interest rates.
See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on credit agreements, commercial paper issuances, Ameren’s money pool agreements and related borrowings, and relevant interest rates.
The issuance of short-term debt securities by Ameren’s utility subsidiaries is subject to FERC approval under the Federal Power Act. In January 2023, the FERC issued orders authorizing Ameren Missouri, Ameren Illinois, and ATXI to issue up to $1 billion, $1 billion, and $300 million, respectively, of short-term debt securities through January 2025.
The Ameren Companies continually evaluate the adequacy and appropriateness of their liquidity arrangements for changing business conditions. When business conditions warrant, changes may be made to existing credit agreements or to other borrowing arrangements, or other arrangements may be made.
Long-term Debt and Equity
The following table presents issuances (net of any issuance premiums or discounts) of long-term debt and equity, as well as maturities of long-term debt for the nine months ended September 30, 2024 and 2023:

| Month Issued, Redeemed, or Matured |  | 2024 |  | 2023 |
Issuances of Long-term Debt |  |  |  |  |  |
Ameren Missouri: |  |  |  |  |  |
5.25% First mortgage bonds due 2054 | January |  | $ | 347 |  |  | $ | — |  |
5.45% First mortgage bonds due 2053 | March |  | — |  |  | 499 |  |
5.20% First mortgage bonds due 2034 | April |  | 499 |  | — |  |
Ameren Illinois: |  |  |  |  |  |
4.95% First mortgage bonds due 2033 | May |  | — |  |  | 498 |  |
5.55% First mortgage bonds due 2054 | June |  | 624 |  |  | — |  |
ATXI: |  |  |  |  |  |
5.17% Senior unsecured notes due 2039 | August |  | 70 |  |  | — |  |
5.42% Senior unsecured notes due 2053 | August |  | 70 |  |  | — |  |
Total Ameren long-term debt issuances |  |  | $ | 1,610 |  |  | $ | 997 |  |
Issuances of Common Stock |  |  |  |  |  |
Ameren: |  |  |  |  |  |
DRPlus and 401(k)(a)(b) | Various |  | $ | 30 |  |  | $ | 28 |  |
Total Ameren common stock issuances(c) |  |  | $ | 30 |  |  | $ | 28 |  |
Maturities of Long-term Debt |  |  |  |  |  |
Ameren: |  |  |  |  |  |
2.50% Senior unsecured notes due 2024 | September |  | $ | 450 |  |  | $ | — |  |
Ameren Missouri: |  |  |  |  |  |
Audrain County agreement (Audrain County CT) due 2023 | January |  | — |  |  | 240 |  | (d)
3.50% Senior secured notes due 2024 | April |  | 350 |  | — |  |
Ameren Illinois: |  |  |  |  |  |
0.375% First mortgage bonds due 2023 | June |  | — |  |  | 100 |  |
ATXI: |  |  |  |  |  |
3.43% Senior unsecured notes due 2050 | August |  | 49 |  |  | — |  |
Total Ameren long-term debt maturities |  |  | $ | 849 |  |  | $ | 340 |  |

(a)Ameren issued a total of 0.4 million and 0.4 million shares of common stock under its DRPlus and 401(k) plan for the nine months ended September 30, 2024 and 2023, respectively.
(b)Excludes a $7 million and $7 million receivable at September 30, 2024 and 2023, respectively.
(c)Excludes 0.2 million and 0.5 million shares of common stock valued at $16 million and $37 million issued for no cash consideration in connection with stock-based compensation for the nine months ended September 30, 2024 and 2023, respectively.
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(d)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.
In October 2024, Ameren Missouri issued $450 million of 5.125% first mortgage bonds due March 2055, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2025. Net proceeds from this issuance were used for capital expenditures and to repay short-term debt.
See Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for additional information, including proceeds from issuances of long-term debt, the use of those proceeds, Ameren’s forward equity sale agreements, the ATM program, and capital contributions received by Ameren Missouri from Ameren (parent).
Indebtedness Provisions and Other Covenants
At September 30, 2024, the Ameren Companies were in compliance with the provisions and covenants contained in their credit agreements, indentures, and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreements. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for a discussion of provisions, applicable cross-default provisions, and covenants contained in our credit agreements, in ATXI’s note purchase agreements, and in certain of the Ameren Companies’ indentures and articles of incorporation.
We consider access to short-term and long-term capital and credit markets to be a significant source of funding for capital requirements not satisfied by cash provided by our operating activities. Inability to raise capital on reasonable terms, particularly during times of uncertainty in the capital and credit markets, could negatively affect our ability to maintain and expand our businesses. After assessing their respective current operating performance, liquidity, and credit ratings (see Credit Ratings below), Ameren, Ameren Missouri, and Ameren Illinois each believes that it will continue to have access to the capital and credit markets on reasonable terms. However, events beyond Ameren’s, Ameren Missouri’s, or Ameren Illinois’ control may create uncertainty in the capital and credit markets or make access to the capital and credit markets uncertain or limited. Such events could increase our cost of capital and adversely affect our ability to access the capital and credit markets.
Dividends
The amount and timing of dividends payable on Ameren’s common stock are within the sole discretion of Ameren’s board of directors. Ameren’s board of directors has not set specific targets or payout parameters when declaring common stock dividends, but it considers various factors, including Ameren’s overall payout ratio, payout ratios of our peers, projected cash flow and potential future cash flow requirements, historical earnings and cash flow, projected earnings, impacts of regulatory orders or legislation, and other key business considerations. Ameren expects its dividend payout ratio to be between 55% and 65% of annual earnings over the next few years.
See Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for additional discussion of covenants and provisions contained in certain of the Ameren Companies’ financial agreements and articles of incorporation that would restrict the Ameren Companies’ payment of dividends in certain circumstances. At September 30, 2024, none of these circumstances existed at Ameren, Ameren Missouri, or Ameren Illinois and, as a result, these companies were not restricted from paying dividends.
The following table presents common stock dividends declared and paid by Ameren Corporation to its common shareholders and by Ameren subsidiaries to their parent, Ameren Corporation, for the nine months ended September 30, 2024 and 2023:

| Nine Months
| 2024 |  | 2023
Ameren | $ | 535 |  |  | $ | 496 |
Ameren Illinois | 50 |  |  | — |
ATXI | — |  |  | 95 |

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Credit Ratings
Our credit ratings affect our liquidity, our access to the capital and credit markets, our cost of borrowing under our credit facilities and our commercial paper programs, and our collateral posting requirements under commodity contracts.
The following table presents the principal credit ratings by Moody’s and S&P, as applicable, effective on the date of this report:

|  | Moody’s |  | S&P
Ameren: |  |  |  |
Issuer/corporate credit rating |  | Baa1 |  | BBB+
Senior unsecured debt |  | Baa1 |  | BBB
Commercial paper |  | P-2 |  | A-2
Ameren Missouri: |  |  |  |
Issuer/corporate credit rating |  | Baa1 |  | BBB+
Secured debt |  | A2 |  | A
Senior unsecured debt |  | Baa1 |  | Not Rated
Commercial paper |  | P-2 |  | A-2
Ameren Illinois: |  |  |  |
Issuer/corporate credit rating |  | A3 |  | BBB+
Secured debt |  | A1 |  | A
Senior unsecured debt |  | A3 |  | BBB+
Commercial paper |  | P-2 |  | A-2
ATXI: |  |  |  |
Issuer credit rating |  | A2 |  | Not Rated
Senior unsecured debt |  | A2 |  | Not Rated

A credit rating is not a recommendation to buy, sell, or hold securities. It should be evaluated independently of any other rating. Ratings are subject to revision or withdrawal at any time by the rating organization.
Collateral Postings
Any weakening of our credit ratings may reduce access to capital and trigger additional collateral postings and prepayments. Such changes may also increase the cost of borrowing, resulting in an adverse effect on earnings. Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts were immaterial and cash collateral posted by external parties were $61 million for Ameren and Ameren Illinois at September 30, 2024. A sub-investment-grade issuer or senior unsecured debt rating (below “Baa3” from Moody’s or below “BBB-” from S&P) at September 30, 2024, could have resulted in Ameren, Ameren Missouri, or Ameren Illinois being required to post additional collateral or other assurances for certain trade and contractual obligations amounting to $944 million, $870 million, and $74 million, respectively.
Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at September 30, 2024, if market prices were 15% higher or lower than September 30, 2024 levels in the next 12 months and 20% higher or lower thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, and Ameren Illinois could be required to post an immaterial amount, compared to each company’s liquidity, of collateral or provide other assurances for certain trade and contractual obligations.
OUTLOOK
Below are some key trends, events, and uncertainties that may reasonably affect our results of operations, financial condition, or liquidity, as well as our ability to achieve strategic and financial objectives, for 2024 and beyond. For additional information regarding recent rate orders, lawsuits, and pending requests filed with state and federal regulatory commissions, including those discussed below, see Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K.
Operations
•The PISA permits Ameren Missouri to defer and recover 85% of the depreciation expense for investments in qualifying property, plant, and equipment placed in service and not included in base rates. Investments not eligible for recovery under the PISA include amounts related to new nuclear and natural gas generating units and service to new customer premises. Additionally, the PISA permits Ameren Missouri to earn a return at the applicable WACC on rate base that incorporates those qualifying investments, as well as changes in total accumulated depreciation excluding retirements and plant-related deferred income taxes since the previous regulatory rate review. The
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regulatory asset for accumulated PISA deferrals also earns a return at the applicable WACC until added to rate base prospectively. Ameren Missouri recognizes an offset to “Interest Charges” on its consolidated statement of income for its carrying cost of debt relating to each return allowed under the PISA, with the difference between the applicable WACC and its carrying cost of debt recognized in revenues when recovery of PISA deferrals is reflected in customer rates. Approved PISA deferrals are recovered over a period of 20 years following a regulatory rate review. Additionally, under the RESRAM, Ameren Missouri is permitted to recover the 15% of depreciation expense not recovered under the PISA, and earn a return at the applicable WACC for investments in renewable generation plant placed in service to comply with Missouri’s renewable energy standard. Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. The PISA and the RESRAM mitigate the effects of regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under the PISA and the remaining 15% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. As a result of the PISA election, additional provisions of the law apply to Ameren Missouri, including limitations on electric customer rate increases. Pursuant to a Missouri law that became effective in August 2022, Ameren Missouri’s PISA election was extended through December 2028 and an additional extension through December 2033 is allowed if requested by Ameren Missouri and approved by the MoPSC, among other things. This law also established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates, compared to the revenue requirement established in the immediately preceding rate order, due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1, 2024.
•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 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.
•In September 2024, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for natural gas delivery service by $40 million. The MoPSC proceeding relating to the proposed natural gas delivery service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by August 2025 and new rates effective by September 2025. Ameren Missouri cannot predict the level of any natural gas delivery 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.
•In 2018, the MoPSC issued an order approving Ameren Missouri’s MEEIA 2019 plan. The plan includes a portfolio of customer energy-efficiency and demand response programs through December 2024. Ameren Missouri intends to invest $76 million in 2024. The plan includes the use of the MEEIA rider, which allows Ameren Missouri to collect from customers its actual MEEIA program costs and related lost electric revenues. In addition, the plan includes a performance incentive that provides Ameren Missouri an opportunity to earn revenues by achieving certain customer energy-efficiency goals. If the target program spending goal is achieved for 2024, the performance incentive would result in revenues of $12 million in 2024.
•In January 2024, Ameren Missouri filed a proposed customer energy-efficiency plan with the MoPSC under the MEEIA. In October 2024, Ameren Missouri, the MoOPC, and other intervenors filed a nonunanimous stipulation and agreement with the MoPSC for a three-year plan, which includes a portfolio of customer energy-efficiency and demand response programs, along with the continued use of the MEEIA rider discussed above. If the agreement is approved, Ameren Missouri intends to invest $51 million annually in 2025 and 2026 and $22 million in 2027 in the proposed customer energy-efficiency and demand response programs. In addition, the agreement requested performance incentives applicable to each plan year to earn revenues by achieving certain spending and demand response goals. If 100% of the goals are achieved in 2025, 2026, and 2027, Ameren Missouri would earn performance incentive revenues of $5 million, $5 million, and $2 million, respectively. Ameren Missouri expects a decision by the MoPSC in the fourth quarter of 2024, but cannot predict the ultimate outcome of this regulatory proceeding.
•Ameren Illinois and ATXI use a forward-looking rate calculation with an annual revenue requirement reconciliation for each company’s electric transmission business. Based on expected rate base and the currently allowed 10.48% ROE, which includes a 50-basis-point incentive adder for participation in an RTO, the revenue requirements that will be included in 2025 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are $643 million and $232 million, respectively. These revenue requirements represent increases in Ameren Illinois’ and ATXI’s revenue requirements of $94 million and $9 million, respectively, from the revenue requirements reflected in 2024 rates, primarily due to higher expected rate base. These rates will affect Ameren Illinois’ and ATXI’s cash receipts during 2025, but will not determine their respective electric transmission service operating revenues, which will instead be based on 2025 actual recoverable costs, rate base, and a return on rate base at the applicable WACC as calculated under the FERC formula ratemaking framework.
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•The allowed base ROE for FERC-regulated transmission rates previously charged under the MISO tariff has been the subject of pending proceedings since 2013. In October 2024, the FERC issued an order, which decreased the allowed base ROE from 10.02% to 9.98% and required refunds, with interest, for the periods from November 2013 to February 2015 and from late September 2016 forward. In March 2020, the FERC issued a Notice of Proposed Rulemaking on its transmission incentives policy, which proposed to increase the incentive ROE for participation in an RTO to 100 basis points from the current 50 basis points and revised the parameters for awarding incentives, while limiting the overall incentives to a cap of 250 basis points, among other things. In April 2021, the FERC issued a Supplemental Notice of Proposed Rulemaking, which proposed to modify the Notice of Proposed Rulemaking’s incentive for participation in an RTO by limiting this incentive for utilities that join an RTO to 50 basis points and only allowing them to earn the incentive for three years, among other things. If this proposal is included in a final rule, Ameren Illinois and ATXI would no longer be eligible for the 50 basis point RTO incentive adder, prospectively. The FERC is under no deadline to issue a final rule on this matter. Ameren is unable to predict the ultimate impact of any changes to the FERC’s incentives policy. A 50-basis-point change in the FERC-allowed ROE would affect Ameren’s and Ameren Illinois’ annual net income by an estimated $16 million and $11 million, respectively, based on each company’s 2024 projected rate base.
•Pursuant to December 2022 and March 2021 ICC orders, Ameren Illinois used the IEIMA formula framework to establish annual electric distribution service rates effective through 2023, and reconciled the related revenue requirement for customer rates established for 2023. As such, Ameren Illinois’ 2023 revenues reflected actual recoverable costs, year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. By law, the decoupling provisions extend beyond 2023, which ensures that Ameren Illinois’ electric distribution revenues authorized in a regulatory rate review are not affected by changes in sales volumes. 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. 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.
•Pursuant to the CEJA, which was enacted in September 2021, Ameren Illinois may file an MYRP with the ICC to establish base rates for electric distribution service to be charged to customers for each calendar year of a four-year period. The base rates for a particular calendar year are based on forecasted recoverable costs and an ICC-determined ROE applied to Ameren Illinois’ forecasted average annual rate base using a forecasted capital structure, with a common equity ratio of up to 50% being deemed prudent and reasonable by law and a higher equity ratio requiring specific ICC approval. The ROE determined by the ICC for each calendar year of the four-year period is subject to annual adjustments based on certain performance incentives and penalties. An MYRP allows Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis, subject to a reconciliation cap and adjustments to the ROE. Under the MYRP discussed below, Ameren Illinois’ 2024 electric distribution service revenues will be based on its 2024 actual recoverable costs, 2024 year-end rate base, and an ROE of 8.72%, as adjusted for any performance incentives or penalties, provided the actual revenue requirement does not exceed the reconciliation cap. If a given year’s revenue amount collected from customers varies from the approved revenue requirement, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the applicable annual period. Ameren Illinois’ existing riders remain effective under the MYRP discussed below, and will continue to remain effective beyond 2027 whether it elects to file an MYRP or a traditional regulatory rate review. Additionally, electric distribution service revenues continue to be decoupled from sales volumes under either election.
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•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, approving revenue requirements for electric distribution services for 2024, 2025, 2026, and 2027 of $1,196 million, $1,282 million, $1,350 million, and $1,397 million, respectively. New rates became effective in late June 2024. 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. 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. In January 2024, Ameren Illinois filed an appeal of the December 2023 ICC order and subsequently updated the appeal filing in September 2024 to include the June 2024 rehearing order regarding the inclusion of an asset associated with other postretirement benefits in the rate base to the Illinois Appellate Court for the Fifth Judicial District. The court is under no deadline to address the appeal. In September 2024, Ameren Illinois filed an update to its revised Grid Plan and a request to update the associated MYRP revenue requirements for 2024, 2025, 2026, and 2027 to $1,215 million, $1,299 million, $1,385 million, and $1,444 million, respectively. An ICC decision on the revised Grid Plan and updated revenue requirements is expected in December 2024 with rates effective in January 2025. Using the 2023 revenue requirement as a starting point, the requested revenue requirements in Ameren Illinois’ September 2024 revised MYRP filing represent a cumulative four-year increase of $332 million. 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. Ameren Illinois has taken prudent steps to align its 2024 operations with the ICC orders, while continuing to ensure safe and adequate service is maintained. This includes reductions to Ameren Illinois’ capital expenditure and operations and maintenance expense plans.
•Pursuant to Illinois law, Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The allowed ROE on electric energy-efficiency investments can be increased or decreased by up to 200 basis points, depending on the achievement of annual energy savings goals. While the ICC has approved a plan for Ameren Illinois to invest approximately $120 million per year in electric energy-efficiency programs through 2025, the ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs.
•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. The new rates became effective on November 28, 2023. In December 2023, Ameren Illinois filed a request for rehearing with the ICC to revise the approved ROE and capital structure common equity percentage, and reverse an 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. Ameren Illinois has taken prudent steps to align its 2024 operations with the ICC order, while continuing to ensure safe and adequate service is maintained. This includes reductions to Ameren Illinois’ capital expenditure and operations and maintenance expense plans.
•Ameren Illinois expects to file for a natural gas delivery service regulatory rate review in early 2025, with a future test year ended December 31, 2026.
•Ameren Missouri’s next refueling and maintenance outage at its Callaway energy center is scheduled for the spring of 2025. During a scheduled refueling, which occurs every 18 months, maintenance expenses are deferred as a regulatory asset and amortized until the completion of the next refueling and maintenance outage. During an outage, depending on the availability of its other generation sources and the market prices for power, Ameren Missouri’s purchased power costs may increase and the amount of excess power available for sale may decrease versus non-outage years. Changes in purchased power costs and excess power available for sale are included in the FAC, which results in limited impacts to earnings. In addition, Ameren Missouri may incur increased non-nuclear energy center maintenance costs in non-outage years.
•In September 2023, the United States District Court for the Eastern District of Missouri granted Ameren Missouri’s request to modify a September 2019 remedy order issued by the district court in 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. Ameren Missouri retired the
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Rush Island Energy Center on October 15, 2024. The United States Department of Justice is seeking an order from the district court providing for additional mitigation relief related to prior emissions. In November 2024, Ameren Missouri and the United States Department of Justice reached an agreement in principle, which, if approved by the district court, would resolve all outstanding claims in this case and would require Ameren Missouri to fund a program to provide electric buses and charging stations to schools in the metro St. Louis area and a program to provide air purifiers to eligible Ameren Missouri electric residential customers. These programs are estimated to cost approximately $64 million. As of September 30, 2024, Ameren and Ameren Missouri recorded liabilities of $64 million related to the cost of these programs. For additional information on the NSR and Clean Air Act litigation, see Note 9 – Commitments and Contingencies under Part I, Item 1, of this report.
•Pursuant to Illinois law, Ameren Missouri's natural gas-fired energy centers in Illinois are subject to annual limits on emissions, including CO 2 and NO x. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure of the Venice Energy Center by the end of 2029. The reductions could also limit the operations of Ameren Missouri's four other natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to conditions in the CEJA, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service.
•Although the pace of inflation has slowed recently, we are still observing elevated inflation levels that continue to put pressure on the prices of labor, services, materials, and supplies, as well as elevated interest rates. Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel, purchased power, and natural gas supply. Additionally, for certain non-commodity cost changes, the use of trackers, riders, formula ratemaking, and future test years, as applicable, mitigates our exposure. The elevated inflation levels and elevated interest rates could impact our ability to control costs and/or make substantial investments in our businesses, including our ability to recover costs and investments, and to earn our allowed ROEs within frameworks established by our regulators, while maintaining rates that are affordable to our customers. In addition, the elevated inflation levels and elevated interest rates could adversely affect our customers’ usage of, or payment for, our services.
•Ameren Missouri and Ameren Illinois continue to make infrastructure investments and expect to seek increases to electric and natural gas rates to recover the cost of investments and earn an adequate return. Ameren Missouri and Ameren Illinois will also seek new, or to maintain existing, regulatory and legislative solutions to address regulatory lag and to support investment in their utility infrastructure for the benefit of their customers. Ameren Missouri and Ameren Illinois continue to face cost recovery pressures, elevated inflation levels, higher cost of debt, customer conservation efforts, the impacts of additional customer energy-efficiency programs, and increased customer use of increasingly cost-effective advancements in innovative energy technologies, including private generation and energy storage. We expect a net increase in demand resulting from the electrification of the economy, including in the transportation sector. In addition, a new 250-MW data center is expected to be constructed in Ameren Missouri’s service territory and is expected to be in service by 2026. Several other entities in various industries, including data center and manufacturing, are considering either locating or expanding their operations within our service territories. We expect that increased investments, including expected future investments for environmental compliance, system reliability improvements, and new generation sources, will result in rate base and revenue growth but also higher depreciation and financing costs.
Liquidity and Capital Resources
•In September 2023, Ameren Missouri filed its 2023 IRP with the MoPSC, which includes Ameren Missouri’s preferred plan for meeting customers’ projected long-term energy needs in a manner that maintains system reliability and customer affordability while transitioning to clean energy generation in an environmentally responsible manner. In connection with this plan, Ameren is continuing to target net-zero carbon emissions by 2045, as well as a 60% reduction by 2030 and an 85% reduction by 2040 based on 2005 levels. Ameren’s goals include both reduction of direct emissions from operations (scope 1), as well as electricity usage at Ameren buildings (scope 2), including other greenhouse gas emissions of methane, nitrous oxide, and sulfur hexafluoride. Achieving these goals will be dependent on a variety of factors, including cost-effective advancements in innovative clean energy technologies and constructive federal and state energy and economic policies. The preferred plan includes, among other things, the following:
•adding an 800-MW natural gas-fired simple-cycle energy center by 2027, which will be realized through the Castle Bluff Natural Gas Project discussed below, and an additional 1,200-MW natural gas-fired combined-cycle energy center by 2033;
•adding 2,800 MWs of renewable generation by 2030, which includes the solar generation facilities discussed below, and an additional 1,900 MWs by 2036;
•adding 400 MWs of battery storage by 2030 and an additional 400 MWs by 2035;
•adding 1,200 MWs of other clean dispatchable generation resources by 2040 and an additional 1,200 MWs by 2043;
•retiring all of Ameren Missouri’s coal-fired energy centers by 2042;
•accelerating the retirement date of the Rush Island coal-fired energy center, which was retired on October 15, 2024;
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•extending the retirement date of the Sioux coal-fired energy center from 2030 to 2032 to ensure reliability during the transition to clean energy generation, which is subject to the approval of a change in depreciable lives of the energy center’s assets by the MoPSC;
•retiring 1,800 MWs of Ameren Missouri’s natural gas-fired energy centers by 2040 to comply with Illinois law;
•the continued implementation of customer energy-efficiency and demand response programs; and
•the expectation that Ameren Missouri will seek and receive NRC approval for an extension of the operating license for the Callaway Energy Center beyond its current 2044 expiration date.
Expected capital expenditures through 2028 related to the facilities discussed above are included in Ameren’s and Ameren Missouri’s expected capital investments discussed below. Ameren Missouri’s plan could be affected by, among other factors: Ameren Missouri’s ability to obtain CCNs from the MoPSC, and any other required approvals for the addition of renewable resources or natural gas-fired generation, retirement of energy centers, and new or continued customer energy-efficiency programs; the ability to enter into agreements for renewable or natural gas-fired generation and acquire or construct that generation at a reasonable cost; the ability of suppliers, contractors, and developers to meet contractual commitments and timely complete projects, which is dependent upon the availability of necessary labor, materials, and equipment, geopolitical conflict, or government actions, among other things; changes in the scope and timing of projects; the ability to qualify for, and use or transfer, federal production or investment tax credits; the cost of wind, solar, and other renewable generation and battery storage technologies; the cost of natural gas or hydrogen CT technologies; the ability to maintain system reliability during and after the transition to clean energy generation; new and/or changes in environmental regulations, including those related to CO 2 and other greenhouse gas emissions; energy prices and demand; Ameren Missouri’s ability to obtain necessary rights-of-way, easements, and transmission interconnection agreements at an acceptable cost and in a timely fashion; the ability to earn an adequate return on invested capital; and the ability to raise capital on reasonable terms. A new data center is expected to be constructed in Ameren Missouri’s service territory by 2026 and several entities are considering either locating or expanding their operations within Ameren Missouri’s service territory. As such, Ameren Missouri currently expects to update its 2023 IRP by February 2025, following its evaluation of potential load growth and its generation portfolio. The next integrated resource plan is required to be filed by October 2026.
•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 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 under Part I, Item 1, of this report. However, claims regarding such actions could be considered in future regulatory proceedings. Base rate revenues relating to the recovery of the Rush Island Energy Center are being deferred as a regulatory liability since the October 15, 2024 retirement date of the facility.
•Ameren Missouri, and certain subsidiaries of Ameren Missouri, are parties to agreements to acquire and/or construct various generation facilities. All regulatory approvals have been obtained. Ameren Missouri acquired the Cass County, Boomtown, and Huck Finn solar projects in June 2024, September 2024, and October 2024, respectively. These three acquisitions collectively represent a purchase price of approximately $0.9 billion. In October 2024, the MoPSC issued an order approving a nonunanimous stipulation and agreement filed by Ameren Missouri, the MoPSC staff, and other intervenors requesting a CCN for the Castle Bluff Natural Gas Project. The order also includes the use of a post-construction cost deferral related to the project which allows Ameren Missouri to defer and recover depreciation expense, financing costs, and applicable income taxes incurred from the date the project is placed in service to the date when project costs are reflected in updated base rates as a result of a regulatory rate review. The period of deferral would be limited to the earlier of the time the project costs are reflected in base rates or six months. All of the generation facilities are aligned with the 2023 IRP discussed above, and expected capital expenditures related to these facilities are included in Ameren’s and Ameren Missouri’s expected capital investments discussed below.
•Through 2028, we expect to make significant capital expenditures to improve our electric and natural gas utility infrastructure, with a major portion directed to our transmission and distribution systems. We estimate that we will invest up to $22.8 billion (Ameren Missouri – up to $13.5 billion; Ameren Illinois – up to $7.6 billion; ATXI – up to $1.7 billion) of capital expenditures during the period from 2024 through 2028. Ameren’s and Ameren Missouri’s estimates include $3.3 billion of renewable generation investments and $2.7 billion of dispatchable generation investments through 2028, consistent with Ameren Missouri’s 2023 IRP. Ameren’s and Ameren Illinois’ estimates include investments necessary to meet compliance requirements of the CEJA, while continuing to ensure safe and adequate service is maintained. Ameren Illinois’ estimates may be revised as a result of future ICC orders related to its current MYRP.
•In 2021, the MISO issued a report outlining a preliminary long-range transmission planning roadmap of projects through 2039, which considers the rapidly changing generation mix within MISO resulting from significant additions of renewable generation, actual and
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expected generation plant closures, and state mandates or goals for clean energy or carbon emissions reductions. In July 2022, the MISO approved the first tranche of projects under the roadmap. A portion of these projects were assigned to various utilities, of which Ameren was awarded projects that are estimated to cost approximately $1.8 billion, based on the MISO’s cost estimate. Related to these projects, Ameren began substation upgrades in May 2024 in advance of transmission line construction, which is expected to begin in 2026, with forecasted completion dates near the end of this decade. In addition, the MISO awarded two competitive bid projects to ATXI in the fourth quarter of 2023 and one in April 2024 that represent a total estimated investment of approximately $220 million for ATXI. 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. 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 expects to construct within the MoPSC’s jurisdiction. A decision by the MoPSC is expected by mid-2025. In September 2024, the MISO revised a proposed first set of second tranche projects with estimated costs of $21.8 billion, which includes projects located in our service territories of $3.6 billion, based on the MISO’s cost estimate. The MISO is expected to approve this set of projects by the end of 2024. The MISO expects to begin developing an additional set of second tranche projects in 2025.
•Environmental regulations, including those related to CO 2 emissions, or other actions taken by the EPA or state regulators, or requirements that may result from the NSR and Clean Air Act Litigation, could result in significant increases in capital expenditures and operating costs. Regulations can be reviewed and repealed, and replacement or alternative regulations can be proposed or adopted by the regulatory agencies, including the EPA. See Note 9 – Commitments and Contingencies under Part I, Item 1, of this report, for additional information on environmental matters, including the NSR and Clean Air Act litigation. The ultimate implementation of any of these new regulations, as well as the timing of any such implementation, is uncertain. However, the individual or combined effects of existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of some of Ameren Missouri’s coal and natural gas-fired energy centers. Ameren Missouri’s operating costs and capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances, as well as regulatory lag. The cost of Ameren Illinois’ purchased power and natural gas purchased for resale could increase. However, Ameren Illinois expects that these costs would be recovered from customers with no material adverse effect on its results of operations, financial position, or liquidity. Ameren’s and Ameren Missouri’s earnings could benefit from increased investment to comply with environmental regulations if those investments are reflected and recovered on a timely basis in customer rates.
•The Ameren Companies have multiyear credit agreements that cumulatively provide $2.6 billion of credit through December 2027, subject to a 364-day repayment term for Ameren Missouri and Ameren Illinois, with the option to seek incremental commitments to increase the cumulative credit provided to $3.2 billion. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of the Form 10-K for additional information regarding the Credit Agreements. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for long-term debt maturities from 2024 to 2028 and beyond at Ameren (parent), Ameren Missouri, Ameren Illinois, and ATXI. See Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for outstanding forward sale agreements under the ATM and issuances and maturities of long-term debt in 2024 through the date of this report. The use of cash provided by operating activities and short-term borrowings to fund capital expenditures and other long-term investments at the Ameren Companies frequently results in a working capital deficit, defined as current liabilities exceeding current assets, as was the case at September 30, 2024, for Ameren, Ameren Missouri, and Ameren Illinois. Ameren, Ameren Missouri, and Ameren Illinois each believe that their liquidity is adequate given their respective expected operating cash flows, capital expenditures, and financing plans, and expect to continue to have access to the capital and credit markets on reasonable terms when needed. However, there can be no assurance that significant changes in economic conditions, disruptions in the capital and credit markets, or other unforeseen events will not materially affect their ability to execute their expected operating, capital, or financing plans.
•Ameren expects its cash used for currently planned capital expenditures and dividends to exceed cash provided by operating activities over the next several years. As part of its funding plan for capital expenditures, Ameren is using newly-issued shares of common stock to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 2028. Additionally, Ameren has an ATM program under which Ameren may offer and sell from time to time common stock, which includes the ability to enter into forward sales agreements, subject to market conditions and other factors. As of September 30, 2024, Ameren had multiple forward sale agreements that could be settled under the ATM program with various counterparties relating to 4.7 million shares of common stock. Ameren expects to settle approximately $230 million of the forward sale agreements with physical delivery of 2.9 million shares of common stock by December 31, 2024. Including issuances under the DRPlus and employee benefit plans, Ameren plans to issue approximately $300 million of equity in 2024 and approximately $600 million of equity each year from 2025 to 2028. As of September 30, 2024, Ameren had approximately $615 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of September 30, 2024. The Ameren Companies expect their equity to total capitalization to support solid investment-grade credit ratings. Ameren Missouri and Ameren Illinois expect to fund cash flow needs through debt issuances, cash provided by operating activities, and/or capital contributions from Ameren (parent).
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•The IRA was enacted in August 2022, and includes various income tax provisions, among other things. The law extends federal production and investment tax credits for projects beginning construction through 2024 and allows for a 10% adder to the production and investment tax credits for siting projects at existing energy communities as defined in the law, which includes sites previously used for coal-fired generation. The law also creates clean energy tax credits for projects placed in service after 2024. The clean energy tax credits will apply to renewable energy production and investments, along with certain nuclear energy production, and will be phased out beginning in 2033, at the earliest. The phase-out is triggered when greenhouse gas emissions from the electric generation industry are reduced by at least 75% from the annual 2022 emission rate or at the beginning of 2033, whichever is later. The law allows for transferability to an unrelated party for cash of up to 100% of certain tax credits generated after 2022. In addition, the new law imposes a 15% minimum tax on adjusted financial statement income, as defined in the law, for corporations whose average annual adjusted financial statement income exceeds $1 billion for three consecutive preceding tax years effective for tax years beginning after December 31, 2022. Once a corporation exceeds this three-year average annual adjusted financial statement income threshold, it will be subject to the minimum tax for all future tax years. Additional regulations, interpretations, amendments, or technical corrections to or in connection with the IRA have been and are expected to be issued by the IRS or United States Department of Treasury, which may impact the timing of when the 15% minimum tax becomes applicable for Ameren as discussed below.
•Pursuant to the IRA discussed above, Ameren expects to transfer production tax credits generated by Ameren Missouri’s High Prairie Renewable and Atchison Renewable energy centers, as well as production or investment tax credits related to the solar facilities included in Ameren Missouri’s 2023 IRP discussed above, to unrelated third parties from 2024 to 2028.
•In April 2023, the IRS issued guidance providing a safe harbor method of accounting for the capitalization or deduction of certain expenditures to maintain, repair, replace, or improve natural gas distribution property. Ameren expects to adopt this guidance for the 2024 tax year, but is still evaluating its potential impact.
•In June 2024, the IRS issued a series of private letter rulings to another taxpayer which provided guidance on applying IRS normalization rules to the calculation of tax benefits related to net operating loss carryforwards. The rulings concluded that for ratemaking purposes, net operating loss carryforwards should be reflected on a separate company basis and should not be reduced by payments received for the utilization of losses by other affiliates under a tax allocation agreement. While a private letter ruling issued to another taxpayer may not be relied on as precedent, Ameren Missouri, Ameren Illinois, and ATXI are evaluating this guidance and are addressing potential impacts of the private letter rulings with the MoPSC, ICC, and FERC. For Ameren Illinois and ATXI, these impacts could result in material reductions to their regulatory liabilities related to excess deferred taxes resulting from the TCJA. For Ameren Missouri and Ameren Illinois, these impacts could result in material increases to their accumulated deferred income tax assets for ratemaking purposes, which would result in overall increases to their rate bases. Ameren Missouri, Ameren Illinois, and ATXI will record the impacts, if any, upon further evaluation with their respective regulatory commissions.
•As of September 30, 2024, Ameren had $113 million in tax benefits from federal and state income tax credit carryforwards, $41 million in tax benefits from state net operating loss carryforwards, and $24 million in tax overpayments, refunds, and receivables, which will be utilized in future periods. Future expected income tax payments are based on expected taxable income, available income tax credit and net operating loss carryforwards, and current tax law. Expected taxable income is affected by expected capital expenditures, when property, plant, and equipment is placed in-service or retired, and the timing of regulatory reviews, among other things. Based on preliminary calculations, Ameren does not expect to be subject to the 15% minimum tax on adjusted financial statement income imposed by the IRA through 2028. Ameren expects annual federal income tax payments to be immaterial through 2028.
The above items could have a material impact on our results of operations, financial position, and liquidity. Additionally, in the ordinary course of business, we evaluate strategies to enhance our results of operations, financial position, and liquidity. These strategies may include acquisitions, divestitures, opportunities to reduce costs or increase revenues, and other strategic initiatives to increase Ameren’s shareholder value. We are unable to predict which, if any, of these initiatives will be executed. The execution of these initiatives may have a material impact on our future results of operations, financial position, or liquidity.
REGULATORY MATTERS
See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
There have been no material changes to the quantitative and qualitative disclosures about interest rate risk, credit risk, commodity price risk, investment price risk, and commodity supplier risk included in the Form 10-K. See Item 7A under Part II of the Form 10-K for a more detailed discussion of our market risk.
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ITEM 4. CONTROLS AND PROCEDURES.
(a)Evaluation of Disclosure Controls and Procedures
As of September 30, 2024, evaluations were performed under the supervision and with the participation of management, including the principal executive officer and the principal financial officer of each of the Ameren Companies, of the effectiveness of the design and operation of such registrant’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act). Based on those evaluations, as of September 30, 2024, the principal executive officer and the principal financial officer of each of the Ameren Companies concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in such registrant’s reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to its management, including its principal executive officer and its principal financial officer, to allow timely decisions regarding required disclosure.
(b)Changes in Internal Controls over Financial Reporting
There has been no change in any of the Ameren Companies’ internal control over financial reporting during their most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, each of their internal control over financial reporting.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS.
We are involved in legal and administrative proceedings before various courts and 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 this report, will not have a material adverse effect on our results of operations, financial position, or liquidity. Risk of loss is mitigated, in some cases, by insurance or contractual or statutory indemnification. We believe that we have established appropriate reserves for potential losses. For additional information on material legal and administrative proceedings, see Note 2 – Rate and Regulatory Matters, Note 9 – Commitments and Contingencies, and Note 10 – Callaway Energy Center, under Part I, Item 1, of this report. Pursuant to Item 103(c)(3)(iii) of Regulation S-K, our policy is to disclose environmental proceedings to which a governmental entity is a party if we reasonably believe such proceedings will result in monetary sanctions of $1 million or more.
ITEM 1A. RISK FACTORS.
For a detailed discussion of our risk factors, see the information disclosed in Part I, Item 1A, of the Form 10-K.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.
Ameren Corporation, Ameren Missouri, and Ameren Illinois did not purchase equity securities reportable under Item 703 of Regulation S-K during the period from July 1, 2024, to September 30, 2024.
ITEM 5. OTHER INFORMATION.
Insider Adoption or Termination of Trading Arrangements
During the fiscal quarter ended September 30, 2024, none of our directors or officers informed us of the adoption or termination of a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as those terms are defined in Regulation S-K, Item 408.
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ITEM 6. EXHIBITS.
The documents listed below are being filed or have previously been filed on behalf of the Ameren Companies and are incorporated herein by reference from the documents indicated and made a part hereof. Exhibits not identified as previously filed are filed herewith.

Exhibit Designation |  | Registrant(s) |  | Nature of Exhibit |  | Previously Filed as Exhibit to:
Articles of Incorporation/By-Laws
3.1 |  | Ameren |  | Ameren Corporation By-Laws, as amended effective August 9, 2024 |  | August 9, 2024 Form 8-K, Exhibit 3.1, File No. 1-14756
Instruments Defining Rights of Security Holders, Including Indentures
4.1 |  | Ameren |  | Note Purchase Agreement, dated as of August 30, 2024, between Ameren Transmission Company of Illinois and the several purchasers named therein. |  |
4.2 |  | Ameren Missouri |  | Supplemental Indenture to the Ameren Missouri Mortgage dated September 1, 2024, for 5.125% First Mortgage Bonds due 2055 |  | October 7, 2024 Form 8-K, Exhibit 4.2, File No. 1-14756
Rule 13a-14(a) / 15d-14(a) Certifications
31.1 |  | Ameren |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren |  |
31.2 |  | Ameren |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren |  |
31.3 |  | Ameren Missouri |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Missouri |  |
31.4 |  | Ameren Missouri |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Missouri |  |
31.5 |  | Ameren Illinois |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Illinois |  |
31.6 |  | Ameren Illinois |  | Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Illinois |  |
Section 1350 Certifications
32.1 |  | Ameren |  | Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren |  |
32.2 |  | Ameren Missouri |  | Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Missouri |  |
32.3 |  | Ameren Illinois |  | Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Illinois |  |
Interactive Data Files
101.INS |  | Ameren Companies |  | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document |  |
101.SCH |  | Ameren Companies |  | Inline XBRL Taxonomy Extension Schema Document |  |
101.CAL |  | Ameren Companies |  | Inline XBRL Taxonomy Extension Calculation Linkbase Document |  |
101.LAB |  | Ameren Companies |  | Inline XBRL Taxonomy Extension Label Linkbase Document |  |
101.PRE |  | Ameren Companies |  | Inline XBRL Taxonomy Extension Presentation Linkbase Document |  |
101.DEF |  | Ameren Companies |  | Inline XBRL Taxonomy Extension Definition Document |  |
104 |  | Ameren Companies |  | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) |  |

The file number references for the Ameren Companies’ filings with the SEC are: Ameren, 1-14756; Ameren Missouri, 1-2967; and Ameren Illinois, 1-3672.
Each registrant hereby undertakes to furnish to the SEC upon request a copy of any long-term debt instrument not listed above that such registrant has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.
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SIGNATURES
Pursuant to the requirements of the Exchange Act, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

AMEREN CORPORATION (Registrant)
/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)
UNION ELECTRIC COMPANY (Registrant)
/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)
AMEREN ILLINOIS COMPANY (Registrant)
/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date: November 7, 2024
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