Ameren Illinois Q3 common-shareholder income falls to $144M
A proposed $28 million electric distribution adjustment could be collected from customers in 2027 if approved.
Sentiment and the balance of points
Rhea-AI Sentiment reads the wording of the document, how positive or negative its language is on a 1 to 5 scale. The balance of points shown with the takes weighs what the document actually discloses, so the two can disagree, for example when a trial that missed its main goal is described in upbeat language.
Form Type
10-Q
Rhea-AI Filing Summary
Ameren Illinois Co (AILIH) reported third-quarter operating revenue of $1.053 billion, compared with $946 million a year earlier. Electric revenue was $917 million and natural gas revenue was $136 million. Operating income was $244 million, versus $202 million, while net income available to the common shareholder was $144 million versus $148 million. For the first nine months of 2026, revenue was $3.180 billion and common-shareholder net income was $547 million, compared with $2.889 billion and $521 million, respectively, in 2025.
In August 2026, Ameren Illinois issued $400 million of 5.50% first mortgage bonds due September 2036; net proceeds were used to repay short-term debt. It updated its 2025 electric distribution revenue-reconciliation adjustment, requesting recovery of $28 million. Administrative law judges issued a proposed order consistent with the request; an ICC decision was required by December 2026, and any approved adjustment would be collected from customers in 2027.
Ameren Illinois also filed an electric energy-efficiency plan for 2027 through 2029, with an ICC decision expected in November 2026.
1 point · 0 major0 major · 0 points
How this balance works
Rhea-AI gives every point it takes from this document a weight. Minor counts 1, Moderate 3 and Major 9, so one Major point outweighs several Minor ones. The bar adds up the weights on each side, and when neither side holds more than 65% of the total the balance reads Mixed.
It reads the document as published, with the same rules for every company, and it does not look at what the market expected or at how the stock traded, so a point can be objectively good on a day the stock falls.
Rhea-AI Sentiment measures something else, the tone of the wording.
Positive
- Moderate pointThird-quarter operating revenue was $1.053 billion, versus $946 million a year earlier.
Negative
- None.
Key Figures
Operating revenue: $1.053 billion
Operating income: $244 million
Net income available to common shareholder: $144 million
+5 more
8 metrics
Operating revenue
$1.053 billion
Three months ended September 30, 2026; $946 million in 2025.
Operating income
$244 million
Three months ended September 30, 2026; $202 million in 2025.
Net income available to common shareholder
$144 million
Three months ended September 30, 2026; $148 million in 2025.
Operating revenue
$3.180 billion
Nine months ended September 30, 2026; $2.889 billion in 2025.
Net income available to common shareholder
$547 million
Nine months ended September 30, 2026; $521 million in 2025.
First mortgage bond principal
$400 million
Issued August 2026 at 5.50%; due September 2036.
Electric distribution revenue-reconciliation adjustment request
$28 million
Updated request; proposed order consistent with it, with any approved adjustment collected from customers in 2027.
Annual electric energy-efficiency plan investments
Up to $192 million in 2027; up to $239 million in 2028; up to $276 million in 2029
Amounts in Ameren Illinois' plan filed with the ICC.
Key Terms
Revenue Requirement Reconciliation Adjustment, rate base, first mortgage bonds, MYRP
4 terms
Revenue Requirement Reconciliation Adjustment regulatory
"2025 Electric Distribution Service Revenue Requirement Reconciliation Adjustment Review"
rate base financial
"a rate base of $3.2 billion"
Rate base is the dollar value of the physical assets and capital a regulated utility uses to deliver its service — things like power plants, pipes, or equipment. Regulators use that value as the starting point to set prices the utility can charge by allowing a specific percentage return on that base, so a larger or higher-valued rate base usually means higher permitted revenues and therefore directly affects investor earnings and the company's ability to raise capital.
first mortgage bonds financial
"issued $400 million of 5.50% first mortgage bonds due September 2036"
First mortgage bonds are debt securities backed by a company’s property, granting bondholders the primary legal claim to that real estate if the issuer cannot pay. Think of them as being first in line for repayment, like a homeowner’s mortgage lender who gets paid before other creditors. For investors, this priority and the tangible collateral typically make these bonds less risky than unsecured debt, which can mean lower yields but greater protection in bankruptcy.
MYRP regulatory
"four-year MYRP for electric distribution service ratemaking"
FAQ
AI-generated questions and answers. How Rhea-AI works. Not financial advice.
What was AILIH's third-quarter operating revenue?
Ameren Illinois reported $1.053 billion of operating revenue for the three months ended September 30, 2026, compared with $946 million in the same period of 2025. The reported total included $917 million of electric revenue and $136 million of natural gas revenue.
What bonds did Ameren Illinois issue in August 2026?
Ameren Illinois issued $400 million of 5.50% first mortgage bonds due September 2036. Net proceeds from the issuance were used to repay short-term debt.
What is Ameren Illinois' electric energy-efficiency investment plan?
Ameren Illinois filed a plan with annual investments of up to $192 million in 2027, $239 million in 2028, and $276 million in 2029. The ICC may reduce savings goals if insufficient cost-effective programs are available; a decision was expected in November 2026.
AI-generated analysis. How Rhea-AI works. Not financial advice.
Table of Contents
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 | |||||
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. | ||||||
(Missouri Corporation)
(Missouri Corporation)
(Illinois Corporation)
Securities Registered Pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||
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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 | ☒ | No | ☐ | |||||||||||||||||||||||
| Union Electric Company | ☒ | No | ☐ | |||||||||||||||||||||||
| Ameren Illinois Company | ☒ | 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 | ☒ | No | ☐ | |||||||||||||||||||||||
| Union Electric Company | ☒ | No | ☐ | |||||||||||||||||||||||
| Ameren Illinois Company | ☒ | 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 | ☒ | Accelerated filer | ☐ | Non-accelerated filer | ☐ | |||||||||||||||
| Smaller reporting company | Emerging growth company | |||||||||||||||||||
| Union Electric Company | Large accelerated filer | ☐ | Accelerated filer | ☐ | ☒ | |||||||||||||||
| Smaller reporting company | Emerging growth company | |||||||||||||||||||
| Ameren Illinois Company | Large accelerated filer | ☐ | 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 30, 2026, was as follows:
| Registrant | Title of each class of common stock | Shares outstanding | |||||||||
| Ameren Corporation | Common stock, $0.01 par value per share | ||||||||||
| Union Electric Company | Common stock, $5 par value per share, held by Ameren Corporation | ||||||||||
| Ameren Illinois Company | Common stock, no par value, held by Ameren Corporation | ||||||||||
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 | 20 | |||||||
Note 4. Long-term Debt and Equity Financings | 21 | |||||||
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 | 38 | |||||||
| Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 45 | ||||||
| Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 78 | ||||||
| Item 4. | Controls and Procedures | 78 | ||||||
PART II. Other Information | ||||||||
| Item 1. | Legal Proceedings | 78 | ||||||
| Item 1A. | Risk Factors | 78 | ||||||
| Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 78 | ||||||
| Item 5. | Other Information | 78 | ||||||
| Item 6. | Exhibits | 80 | ||||||
Signatures | 81 | |||||||
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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.
2026 PRP – Ameren Missouri’s preferred resource plan for meeting customers’ projected long-term energy needs, which was filed with the MoPSC in September 2026 as a part of its integrated resource plan.
Form 10-K – The combined Annual Report on Form 10-K for the year ended December 31, 2025, 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 or our ability to recover costs and earn a return, such as those that may result from Ameren Missouri’s electric service regulatory rate review filed with the MoPSC in June 2026, Ameren Illinois’ 2025 electric distribution service revenue requirement reconciliation adjustment review filed with the ICC in April 2026, Ameren Illinois’ January 2026 appeal of the November 2025 ICC order issued in the 2025 natural gas delivery service rate review, and Ameren Illinois’ 2020 QIP reconciliation hearing;
•our ability to control costs and make necessary 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 for our customers;
•the effect and duration of Ameren Illinois’ election to utilize a four-year MYRP for electric distribution service ratemaking, including the effect of the reconciliation cap on the electric distribution revenue requirement;
•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 generation and battery energy storage facilities, extend the operating license for the Callaway Energy Center, reliably operate existing energy centers through their expected retirement dates, retire fossil fuel-fired energy centers, and implement new or existing customer energy-efficiency programs, in each case in accordance with its Smart Energy Plan and preferred resource plan, 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 timely obtain and maintain all necessary regulatory and project approvals, including CCNs from the MoPSC or any other required approvals, including permits to construct and operate the facilities;
•our ability to realize and support forecasted energy demand and capacity from new and potential new customers, including demand growth dependent on the addition of new data centers and other large primary service customers within our service territories, such as the large load customers that signed electric service agreements with Ameren Missouri in 2026;
•the effects on energy prices and demand for our services resulting from customer growth patterns or usage, including demand from data centers; technological advances, including advances in customer energy efficiency; electric vehicles; electrification of various industries; energy storage; and private generation sources, which are becoming increasingly cost-competitive;
•Ameren Missouri’s ability to earn, utilize, or transfer at a reasonable price federal production and investment tax credits related to renewable energy, energy storage, and nuclear energy; the cost of wind, solar, and other renewable generation and battery energy storage technologies; and our ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost for each facility;
•the effect of changes in federal domestic energy policy to support investment in fossil fuel infrastructure and the effect of those changes on Ameren Missouri’s ability to construct and/or acquire renewable energy generation facilities and battery energy storage;
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•the results of the MISO long-range transmission planning process, including potential changes to planned projects, the ability to obtain competitively bid or assigned projects and related approvals, including CCNs from the MoPSC and ICC or any other required approvals, and changes in applicable legislative or regulatory frameworks;
•the ability 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 labor and 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 domestic or international governmental actions, including monetary, fiscal, foreign trade, and energy policies, foreign trade tariffs, executive orders, geopolitical developments, or extended federal government shutdowns or defunding;
•the effects of changes in federal, state, or local tax laws or rates; additional regulations, interpretations, amendments, or technical corrections to, or in connection with the OBBBA and the IRA, including the effects of the OBBBA as it relates to construction timelines of solar, wind, and battery energy storage projects, along with the ability to obtain materials for these projects to be eligible for federal production and investment tax credits; and any challenges to the tax positions taken by the Ameren Companies, as well as resulting effects on customer rates;
•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 required 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 at a reasonable cost, 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, including those arising from generative or agentic artificial intelligence, 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, geopolitical, and capital market conditions, including foreign trade tariffs or trade wars, evolving federal regulatory priorities, and the impact of such conditions on interest rates, inflation, commodity prices, and investments;
•the impact of inflation or a recession on our customers and suppliers 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 financing, construction, installation, performance, and cost recovery of generation, transmission, and distribution assets;
•the ability to maintain system reliability by Ameren Missouri, the MISO, and the electric utility industry, as well as Ameren Missouri’s ability to meet existing or future generation capacity and power 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 and environmental policies, including those related to NSR, CO2, NOx, SO2, and other emissions and discharges, Illinois emission standards, cooling water intake structures, CCR, energy efficiency, and wildlife protection, that could limit, terminate or otherwise modify the operation of certain
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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;
•the effectiveness of Ameren Missouri’s customer energy-efficiency programs and the related revenues and performance incentives earned under its MEEIA programs;
•labor disputes, the impact of collective bargaining unit contract negotiations, workforce reductions, our ability to attract and retain professional and skilled-craft employees, changes in future wage and employee benefits costs, including those resulting from changes in discount rates, mortality tables, medical cost trend rates, 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, rating agencies, 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 disagreement with those plans, failure to protect sensitive customer information, increases in rates, data centers entering our service territories, negative media coverage, or concerns about company policies or practices;
•the impact of adopting new accounting and reporting guidance;
•the effects of strategic initiatives, including mergers, acquisitions, joint ventures, divestitures, and reorganizations;
•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 global conflicts and related sanctions imposed by the United States and other governments, including potential impacts on the cost and availability of fuel, natural gas, enriched uranium, and other commodities, materials, and services.
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Operating Revenues: | |||||||||||||||||||||||
| Electric | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas | |||||||||||||||||||||||
| Total operating revenues | |||||||||||||||||||||||
| Operating Expenses: | |||||||||||||||||||||||
| Fuel and purchased power | |||||||||||||||||||||||
| Natural gas purchased for resale | |||||||||||||||||||||||
| Other operations and maintenance | |||||||||||||||||||||||
| Depreciation and amortization | |||||||||||||||||||||||
| Taxes other than income taxes | |||||||||||||||||||||||
| Total operating expenses | |||||||||||||||||||||||
| Operating Income | |||||||||||||||||||||||
| Other Income, Net | |||||||||||||||||||||||
| Interest Charges | |||||||||||||||||||||||
| Income Before Income Taxes | |||||||||||||||||||||||
| Income Taxes | |||||||||||||||||||||||
| Net Income | |||||||||||||||||||||||
| Less: Net Income Attributable to Noncontrolling Interests | |||||||||||||||||||||||
| Net Income Attributable to Ameren Common Shareholders | $ | $ | $ | $ | |||||||||||||||||||
| Earnings per Common Share - Basic | $ | $ | $ | $ | |||||||||||||||||||
| Earnings per Common Share – Diluted | $ | $ | $ | $ | |||||||||||||||||||
| Weighted-average Common Shares Outstanding – Basic | |||||||||||||||||||||||
| Weighted-average Common Shares Outstanding – Diluted | |||||||||||||||||||||||
| Net Income | $ | $ | $ | $ | |||||||||||||||||||
| Other Comprehensive Income (Loss), Net of Taxes | |||||||||||||||||||||||
Pension and other postretirement benefit plan activity, net of income taxes (benefit) of $ | ( | ||||||||||||||||||||||
Unrealized net gains (losses) on derivative hedging instruments, net of income taxes (benefit) of $ | ( | ||||||||||||||||||||||
| Comprehensive Income | |||||||||||||||||||||||
Less: Comprehensive Income Attributable to Noncontrolling Interests | |||||||||||||||||||||||
| Comprehensive Income Attributable to Ameren Common Shareholders | $ | $ | $ | $ | |||||||||||||||||||
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, 2026 | December 31, 2025 | ||||||||||
| ASSETS | |||||||||||
| Current Assets: | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
Accounts receivable – trade (less allowance for doubtful accounts of $ | |||||||||||
| Unbilled revenue | |||||||||||
| Miscellaneous accounts receivable | |||||||||||
| Inventories | |||||||||||
| Current regulatory assets | |||||||||||
| Other current assets | |||||||||||
| Total current assets | |||||||||||
| Property, Plant, and Equipment, Net | |||||||||||
| Investments and Other Assets: | |||||||||||
| Nuclear decommissioning trust fund | |||||||||||
| Goodwill | |||||||||||
Regulatory assets (includes $ | |||||||||||
| Pension and other postretirement benefits | |||||||||||
| Other assets | |||||||||||
| Total investments and other assets | |||||||||||
| TOTAL ASSETS | $ | $ | |||||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current Liabilities: | |||||||||||
Current maturities of long-term debt (includes $ | $ | $ | |||||||||
| Short-term debt | |||||||||||
| Accounts and wages payable | |||||||||||
| Taxes accrued | |||||||||||
| Interest accrued | |||||||||||
| Customer deposits | |||||||||||
| Other current liabilities | |||||||||||
| Total current liabilities | |||||||||||
Long-term Debt, Net (includes $ | |||||||||||
| Deferred Credits and Other Liabilities: | |||||||||||
| Accumulated deferred income taxes and tax credits, net | |||||||||||
| Regulatory liabilities | |||||||||||
| Asset retirement obligations | |||||||||||
| Other deferred credits and liabilities | |||||||||||
| Total deferred credits and other liabilities | |||||||||||
| Commitments and Contingencies (Notes 2, 9, and 10) | |||||||||||
| Shareholders’ Equity: | |||||||||||
Common stock, $ | |||||||||||
| Other paid-in capital, principally premium on common stock | |||||||||||
| Retained earnings | |||||||||||
| Accumulated other comprehensive income | |||||||||||
| Total shareholders’ equity | |||||||||||
| Noncontrolling Interests | |||||||||||
| Total equity | |||||||||||
| TOTAL LIABILITIES AND EQUITY | $ | $ | |||||||||
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, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash Flows From Operating Activities: | |||||||||||
| Net income | $ | $ | |||||||||
| Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
| Depreciation and amortization | |||||||||||
| Amortization of nuclear fuel | |||||||||||
| Amortization of debt issuance costs and premium/discounts | |||||||||||
| Deferred income taxes and tax credits, net | |||||||||||
| Allowance for equity funds used during construction | ( | ( | |||||||||
| Stock-based compensation costs | |||||||||||
| Other | ( | ||||||||||
| Changes in assets and liabilities: | |||||||||||
| Receivables | ( | ( | |||||||||
| Inventories | ( | ( | |||||||||
| Accounts and wages payable | ( | ( | |||||||||
| Taxes accrued | |||||||||||
| Regulatory assets and liabilities | ( | ||||||||||
| Assets, other | ( | ( | |||||||||
| Liabilities, other | |||||||||||
| Pension and other postretirement benefits | ( | ( | |||||||||
| Net cash provided by operating activities | |||||||||||
| Cash Flows From Investing Activities: | |||||||||||
| Capital expenditures | ( | ( | |||||||||
| Nuclear fuel expenditures | ( | ( | |||||||||
| Purchases of securities – nuclear decommissioning trust fund | ( | ( | |||||||||
| Sales and maturities of securities – nuclear decommissioning trust fund | |||||||||||
| Other | ( | ||||||||||
| Net cash used in investing activities | ( | ( | |||||||||
| Cash Flows From Financing Activities: | |||||||||||
| Dividends on common stock | ( | ( | |||||||||
| Dividends paid to noncontrolling interest holders | ( | ( | |||||||||
| Short-term debt, net | ( | ( | |||||||||
| Maturities and extinguishment of long-term debt | ( | ( | |||||||||
| Issuances of long-term debt | |||||||||||
| Issuances of common stock | |||||||||||
| Employee payroll taxes related to stock-based compensation | ( | ( | |||||||||
| Debt issuance costs | ( | ( | |||||||||
| Net cash provided by financing activities | |||||||||||
| Net change in cash, cash equivalents, and restricted cash | |||||||||||
| Cash, cash equivalents, and restricted cash at beginning of year | |||||||||||
| Cash, cash equivalents, and restricted cash at end of period | $ | $ | |||||||||
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Common Stock | $ | $ | $ | $ | |||||||||||||||||||
| Other Paid-in Capital: | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Shares issued under the DRPlus and 401(k) plan | |||||||||||||||||||||||
| Stock-based compensation activity | |||||||||||||||||||||||
| Other paid-in capital, end of period | |||||||||||||||||||||||
| Retained Earnings: | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Net income attributable to Ameren common shareholders | |||||||||||||||||||||||
| Dividends on common stock | ( | ( | ( | ( | |||||||||||||||||||
| Retained earnings, end of period | |||||||||||||||||||||||
| Accumulated Other Comprehensive Income (Loss): | |||||||||||||||||||||||
| Derivative financial instruments, beginning of period | ( | ||||||||||||||||||||||
| Change in derivative financial instruments | ( | ||||||||||||||||||||||
| Derivative financial instruments, end of period | ( | ( | |||||||||||||||||||||
| Deferred retirement benefit costs, beginning of period | ( | ( | ( | ( | |||||||||||||||||||
| Change in deferred retirement benefit costs | ( | ||||||||||||||||||||||
| Deferred retirement benefit costs, end of period | ( | ( | ( | ( | |||||||||||||||||||
| Total accumulated other comprehensive income (loss), end of period | ( | ( | |||||||||||||||||||||
| Total Shareholders’ Equity | $ | $ | $ | $ | |||||||||||||||||||
| Noncontrolling Interests: | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Net income attributable to noncontrolling interest holders | |||||||||||||||||||||||
| Dividends paid to noncontrolling interest holders | ( | ( | ( | ( | |||||||||||||||||||
| Noncontrolling interests, end of period | |||||||||||||||||||||||
| Total Equity | $ | $ | $ | $ | |||||||||||||||||||
| Common stock shares outstanding at beginning of period | |||||||||||||||||||||||
| Shares issued under the DRPlus and 401(k) plan | |||||||||||||||||||||||
| Shares issued for stock-based compensation | |||||||||||||||||||||||
| Common stock shares outstanding at end of period | |||||||||||||||||||||||
| Dividends per common share | $ | $ | $ | $ | |||||||||||||||||||
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Operating Revenues: | |||||||||||||||||||||||
| Electric | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas | |||||||||||||||||||||||
| Total operating revenues | |||||||||||||||||||||||
| Operating Expenses: | |||||||||||||||||||||||
| Fuel and purchased power | |||||||||||||||||||||||
| Natural gas purchased for resale | |||||||||||||||||||||||
| Other operations and maintenance | |||||||||||||||||||||||
| Depreciation and amortization | |||||||||||||||||||||||
| Taxes other than income taxes | |||||||||||||||||||||||
| Total operating expenses | |||||||||||||||||||||||
| Operating Income | |||||||||||||||||||||||
| Other Income, Net | |||||||||||||||||||||||
| Interest Charges | |||||||||||||||||||||||
| Income Before Income Taxes | |||||||||||||||||||||||
| Income Taxes | |||||||||||||||||||||||
| Net Income | |||||||||||||||||||||||
| Preferred Stock Dividends | |||||||||||||||||||||||
| Net Income Available to Common Shareholder | $ | $ | $ | $ | |||||||||||||||||||
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, 2026 | December 31, 2025 | ||||||||||
| ASSETS | |||||||||||
| Current Assets: | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
Accounts receivable – trade (less allowance for doubtful accounts of $ | |||||||||||
| Accounts receivable – affiliates | |||||||||||
| Unbilled revenue | |||||||||||
| Miscellaneous accounts receivable | |||||||||||
| Inventories | |||||||||||
| Current regulatory assets | |||||||||||
| Other current assets | |||||||||||
| Total current assets | |||||||||||
| Property, Plant, and Equipment, Net | |||||||||||
| Investments and Other Assets: | |||||||||||
| Nuclear decommissioning trust fund | |||||||||||
Regulatory assets (includes $ | |||||||||||
| Pension and other postretirement benefits | |||||||||||
| Other assets | |||||||||||
| Total investments and other assets | |||||||||||
| TOTAL ASSETS | $ | $ | |||||||||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | |||||||||||
| Current Liabilities: | |||||||||||
Current maturities of long-term debt (includes $ | $ | $ | |||||||||
| Short-term debt | |||||||||||
| Accounts and wages payable | |||||||||||
| Accounts payable – affiliates | |||||||||||
| Taxes accrued | |||||||||||
| Interest accrued | |||||||||||
| Other current liabilities | |||||||||||
| Total current liabilities | |||||||||||
Long-term Debt, Net (includes $ | |||||||||||
| Long-term Debt, Net - Related Parties | |||||||||||
| Deferred Credits and Other Liabilities: | |||||||||||
| Accumulated deferred income taxes and tax credits, net | |||||||||||
| Regulatory liabilities | |||||||||||
| Asset retirement obligations | |||||||||||
| Other deferred credits and liabilities | |||||||||||
| Total deferred credits and other liabilities | |||||||||||
| Commitments and Contingencies (Notes 2, 8, 9, and 10) | |||||||||||
| Shareholders’ Equity: | |||||||||||
Common stock, $ | |||||||||||
| Other paid-in capital, principally premium on common stock | |||||||||||
| Preferred stock | |||||||||||
| Retained earnings | |||||||||||
| Total shareholders’ equity | |||||||||||
| TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $ | $ | |||||||||
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, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash Flows From Operating Activities: | |||||||||||
| Net income | $ | $ | |||||||||
| Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
| Depreciation and amortization | |||||||||||
| Amortization of nuclear fuel | |||||||||||
| Amortization of debt issuance costs and premium/discounts | |||||||||||
| Deferred income taxes and tax credits, net | |||||||||||
| Allowance for equity funds used during construction | ( | ( | |||||||||
| Other | |||||||||||
| Changes in assets and liabilities: | |||||||||||
| Receivables | ( | ( | |||||||||
| Inventories | ( | ||||||||||
| Accounts and wages payable | ( | ( | |||||||||
| Taxes accrued | |||||||||||
| Regulatory assets and liabilities | ( | ( | |||||||||
| Assets, other | ( | ||||||||||
| Liabilities, other | |||||||||||
| Pension and other postretirement benefits | ( | ( | |||||||||
| Net cash provided by operating activities | |||||||||||
| Cash Flows From Investing Activities: | |||||||||||
| Capital expenditures | ( | ( | |||||||||
| Nuclear fuel expenditures | ( | ( | |||||||||
| Purchases of securities – nuclear decommissioning trust fund | ( | ( | |||||||||
| Sales and maturities of securities – nuclear decommissioning trust fund | |||||||||||
| Money pool advances, net | |||||||||||
| Other | ( | ||||||||||
| Net cash used in investing activities | ( | ( | |||||||||
| Cash Flows From Financing Activities: | |||||||||||
| Dividends on common stock | ( | ||||||||||
| Dividends on preferred stock | ( | ( | |||||||||
| Short-term debt, net | ( | ||||||||||
| Money pool borrowings, net | |||||||||||
| Maturities of long-term debt | ( | ||||||||||
| Issuances of long-term debt | |||||||||||
| Capital contribution from parent | |||||||||||
| Debt issuance costs | ( | ( | |||||||||
| Net cash provided by financing activities | |||||||||||
| Net change in cash, cash equivalents, and restricted cash | |||||||||||
| Cash, cash equivalents, and restricted cash at beginning of year | |||||||||||
| Cash, cash equivalents, and restricted cash at end of period | $ | $ | |||||||||
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Common Stock | $ | $ | $ | $ | |||||||||||||||||||
| Other Paid-in Capital | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Capital contributions from parent | |||||||||||||||||||||||
| Other paid-in capital, end of period | |||||||||||||||||||||||
| Preferred Stock | |||||||||||||||||||||||
| Retained Earnings: | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Net income | |||||||||||||||||||||||
| Dividends on common stock | ( | ( | |||||||||||||||||||||
| Dividends on preferred stock | ( | ( | ( | ( | |||||||||||||||||||
| Retained earnings, end of period | |||||||||||||||||||||||
| Total Shareholders’ Equity | $ | $ | $ | $ | |||||||||||||||||||
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Operating Revenues: | |||||||||||||||||||||||
| Electric | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas | |||||||||||||||||||||||
| Total operating revenues | |||||||||||||||||||||||
| Operating Expenses: | |||||||||||||||||||||||
| Purchased power | |||||||||||||||||||||||
| Natural gas purchased for resale | |||||||||||||||||||||||
| Other operations and maintenance | |||||||||||||||||||||||
| Depreciation and amortization | |||||||||||||||||||||||
| Taxes other than income taxes | |||||||||||||||||||||||
| Total operating expenses | |||||||||||||||||||||||
| Operating Income | |||||||||||||||||||||||
| Other Income, Net | |||||||||||||||||||||||
| Interest Charges | |||||||||||||||||||||||
| Income Before Income Taxes | |||||||||||||||||||||||
| Income Taxes | |||||||||||||||||||||||
| Net Income | |||||||||||||||||||||||
| Preferred Stock Dividends | |||||||||||||||||||||||
| Net Income Available to Common Shareholder | $ | $ | $ | $ | |||||||||||||||||||
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, 2026 | December 31, 2025 | ||||||||||
| ASSETS | |||||||||||
| Current Assets: | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
Accounts receivable – trade (less allowance for doubtful accounts of $ | |||||||||||
| Accounts receivable – affiliates | |||||||||||
| Unbilled revenue | |||||||||||
| Miscellaneous accounts receivable | |||||||||||
| Inventories | |||||||||||
| Prepaid assets | |||||||||||
| Current regulatory assets | |||||||||||
| Other current assets | |||||||||||
| Total current assets | |||||||||||
| Property, Plant, and Equipment, Net | |||||||||||
| Investments and Other Assets: | |||||||||||
| Goodwill | |||||||||||
| Regulatory assets | |||||||||||
| Pension and other postretirement benefits | |||||||||||
| Other assets | |||||||||||
| Total investments and other assets | |||||||||||
| TOTAL ASSETS | $ | $ | |||||||||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | |||||||||||
| Current Liabilities: | |||||||||||
| Short-term debt | $ | $ | |||||||||
| Accounts and wages payable | |||||||||||
| Accounts payable – affiliates | |||||||||||
| Interest accrued | |||||||||||
| Customer deposits | |||||||||||
| Mark-to-market derivative liabilities | |||||||||||
| Purchase of receivables liabilities | |||||||||||
| Current regulatory liabilities | |||||||||||
| Other current liabilities | |||||||||||
| Total current liabilities | |||||||||||
| Long-term Debt, Net | |||||||||||
| Long-term Debt, Net – Related Parties | |||||||||||
| Deferred Credits and Other Liabilities: | |||||||||||
| Accumulated deferred income taxes and tax credits, net | |||||||||||
| Regulatory liabilities | |||||||||||
| Other deferred credits and liabilities | |||||||||||
| Total deferred credits and other liabilities | |||||||||||
| Commitments and Contingencies (Notes 2, 8, and 9) | |||||||||||
| Shareholders’ Equity: | |||||||||||
Common stock, | |||||||||||
| Other paid-in capital | |||||||||||
| Preferred stock | |||||||||||
| Retained earnings | |||||||||||
| Total shareholders’ equity | |||||||||||
| TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $ | $ | |||||||||
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, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash Flows From Operating Activities: | |||||||||||
| Net income | $ | $ | |||||||||
| Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
| Depreciation and amortization | |||||||||||
| Amortization of debt issuance costs and premium/discounts | |||||||||||
| Deferred income taxes and investment tax credits, net | |||||||||||
| Allowance for equity funds used during construction | ( | ( | |||||||||
| Other | |||||||||||
| Changes in assets and liabilities: | |||||||||||
| Receivables | ( | ( | |||||||||
| Inventories | ( | ( | |||||||||
| Accounts and wages payable | ( | ||||||||||
| Taxes accrued | ( | ||||||||||
| Regulatory assets and liabilities | ( | ||||||||||
| Assets, other | ( | ( | |||||||||
| Liabilities, other | |||||||||||
| Pension and other postretirement benefits | ( | ( | |||||||||
| Net cash provided by operating activities | |||||||||||
| Cash Flows From Investing Activities: | |||||||||||
| Capital expenditures | ( | ( | |||||||||
| Money pool advances, net | ( | ||||||||||
| Other | ( | ( | |||||||||
| Net cash used in investing activities | ( | ( | |||||||||
| Cash Flows From Financing Activities: | |||||||||||
| Dividends on common stock | ( | ( | |||||||||
| Dividends on preferred stock | ( | ( | |||||||||
| Short-term debt, net | ( | ||||||||||
| Money pool borrowings, net | ( | ||||||||||
| Maturities of long-term debt | ( | ||||||||||
| Issuances of long-term debt | |||||||||||
| Debt issuance costs | ( | ( | |||||||||
| Net cash provided by financing activities | |||||||||||
| Net change in cash, cash equivalents, and restricted cash | |||||||||||
| Cash, cash equivalents, and restricted cash at beginning of year | |||||||||||
| Cash, cash equivalents, and restricted cash at end of period | $ | $ | |||||||||
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, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Common Stock | $ | $ | $ | $ | |||||||||||||||||||
| Other Paid-in Capital | |||||||||||||||||||||||
| Preferred Stock | |||||||||||||||||||||||
| Retained Earnings: | |||||||||||||||||||||||
| Beginning of period | |||||||||||||||||||||||
| Net income | |||||||||||||||||||||||
| Dividends on common stock | ( | ( | ( | ||||||||||||||||||||
| Dividends on preferred stock | ( | ( | |||||||||||||||||||||
| Retained earnings, end of period | |||||||||||||||||||||||
| Total Shareholders’ Equity | $ | $ | $ | $ | |||||||||||||||||||
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, 2026
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 in the MISO.
Ameren’s and Ameren Missouri’s financial statements are prepared on a consolidated basis and therefore include the accounts of their majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Illinois has no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.
Note 1 – Summary of Significant Accounting Policies applies to the Ameren Companies. The remaining notes to the consolidated financial statements apply to the registrants as indicated in each footnote disclosure. Registrants are named specifically for their related activities and disclosures.
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 reported 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 contained in this Form 10-Q should be read in conjunction with the audited financial statements and accompanying notes included in the Form 10-K.
Variable Interest Entities
Variable Interest Entities that are Consolidated
AMF was formed in 2024 for the purpose of issuing and servicing securitized utility tariff bonds related to costs for the accelerated retirement of the Rush Island Energy Center. Ameren Missouri is the primary beneficiary of this entity because it has the power to direct the activities that most significantly impact the economic performance of the entity, as well as the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the variable interest entity. The entity is considered a variable interest entity primarily because its equity capitalization is insufficient to support its operations. The entity’s primary assets and liabilities are comprised of regulatory assets related to the unrecovered net plant balance associated with the retired energy center, among other costs, and long-term debt. Ameren and Ameren Missouri consolidate AMF, which Ameren Missouri wholly owns, and both manages and controls the entity’s operating activities.
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The following table presents the carrying values of AMF’s assets and liabilities included on Ameren’s and Ameren Missouri’s consolidated balance sheets as of September 30, 2026 and December 31, 2025:
| 2026 | 2025 | |||||||||||||
Unbilled revenue(a) | $ | $ | ||||||||||||
Other current assets(a) | ||||||||||||||
Noncurrent regulatory assets(a) | ||||||||||||||
Current maturities of long-term debt(b) | ||||||||||||||
Interest accrued(b) | ||||||||||||||
Current regulatory liabilities(c) | ||||||||||||||
Long-term debt, net(b) | ||||||||||||||
(a)Assets may be used only to meet AMF’s obligations and commitments.
(b)The securitized tariff bondholders have no recourse to Ameren Missouri.
(c)Included in “Other current liabilities” on Ameren’s and Ameren Missouri’s balance sheets.
Variable Interest Entities that are not Consolidated
As of September 30, 2026, and December 31, 2025, Ameren had unconsolidated variable interests in various equity method investments, primarily to advance innovative energy technologies, totaling $92 million and $64 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Any earnings or losses related to Ameren’s share in 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, 2026, Ameren’s maximum exposure to loss related to these variable interest entities is limited to the investment in these entities of $92 million plus associated outstanding funding commitments of $25 million.
COLI
Accounting and Reporting Developments
See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for additional information about recently issued authoritative accounting standards related to internal-use software and government grants.
Accounting for Environmental Credit Programs
In May 2026, the FASB issued authoritative guidance that established requirements for the recognition, measurement, presentation, and disclosure of environmental credits and environmental credit obligations. The guidance applies to all entities that generate, purchase, or receive environmental credits, or that have a regulatory compliance obligation that may be settled with environmental credits. The guidance will be effective for the Ameren Companies beginning January 1, 2028. We are currently assessing the impacts of this guidance on our results of operations, financial position, and liquidity.
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.
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Missouri
2026 Electric Service Regulatory Rate Review
In June 2026, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $343 million. The electric rate request is based on a 10.25 % return on common equity, a capital structure composed of 52 % common equity, a rate base of $16.7 billion, and a test year ended March 31, 2026, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2026. Ameren Missouri also requested the continued use of all of its existing riders and trackers. The electric rate request reflects the following:
•increased transmission and distribution infrastructure investments to support system reliability and resiliency;
•investments in existing generation resources and 400 MWs of new generation resources; and
•the increase for the items above is partially offset by accelerating the benefits of investment tax credits to customers.
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 2027 and new rates effective by June 2027. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be continued, or whether any rate change that may eventually be approved will be sufficient for Ameren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.
Generation and Storage Facilities
Ameren Missouri is party to agreements to acquire and/or construct various generation and storage facilities that are consistent with the 2026 PRP. The generation and storage facilities are eligible for recovery under the PISA, subject to regulatory approval. The following table provides information about each facility:
| Agreement type | Facility size | Status of MoPSC CCN | Status of FERC approval of acquisition | In-service date(a) | |||||||||||||
Bowling Green Solar Project(b) | Self-build | Approved March 2024 | Not applicable | March 2026 | |||||||||||||
| Split Rail Solar Project | Build-transfer(c) | Approved March 2024 | Received November 2024 | June 2026 | |||||||||||||
Castle Bluff Natural Gas Project(b) | Self-build | Approved October 2024 | Not applicable | Fourth quarter 2027 | |||||||||||||
Big Hollow Battery Energy Storage Project(b) | Self-build | Approved February 2026 | Not applicable | Second quarter 2028 | |||||||||||||
Big Hollow Natural Gas Project(b) | Self-build | Approved February 2026 | Not applicable | Third quarter 2028 | |||||||||||||
Reform Solar Project(b) | Self-build | Approved May 2026 | Not applicable | Fourth quarter 2028 | |||||||||||||
Castle Bluff Battery Energy Storage Project(b) | Self-build | Approved October 2026 | Not applicable | Second quarter 2028 | |||||||||||||
Millcreek Battery Energy Storage Project(b) | Self-build | Approved October 2026 | Not applicable | Second quarter 2028 | |||||||||||||
Huck Finn Battery Energy Storage Project(b) | Self-build | Approved October 2026 | Not applicable | Second quarter 2028 | |||||||||||||
Tom Sawyer Solar Project(b) | Build-transfer | Approved October 2026 | Received September 2026 | Fourth quarter 2028 | |||||||||||||
| Ringer Solar Project | Build-transfer | Approved October 2026 | Expect to request by mid-2027 | Second quarter 2029 | |||||||||||||
| West Alton Natural Gas Project | Self-build | Filed July 2026(d) | Not applicable | Fourth quarter 2031 | |||||||||||||
(a)Future in-service dates, which were estimated in each CCN filing, are dependent on the timing of regulatory approvals and construction completion, among other things.
(b)These projects collectively represent approximately $5 billion of capital expenditures.
(c)In February 2026, Ameren Missouri acquired the Split Rail Solar Project for approximately $0.6 billion.
(d)Ameren Missouri expects a decision by the MoPSC in the first half of 2027.
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Illinois
MYRP
In December 2024, the ICC issued an order in connection with a revised Grid Plan and a revised MYRP filed by Ameren Illinois in March 2024, approving revenue requirements for electric distribution services for 2024 through 2027 of $1,206 million, $1,287 million, $1,367 million, and $1,421 million, respectively. In May 2026, the Illinois Appellate Court for the Fifth Judicial District upheld the ICC’s December 2024 order and orders issued by the ICC in June 2024 and December 2023 following appeals by Ameren Illinois.
2024 Electric Distribution Service Revenue Requirement Reconciliation Adjustment Order
In December 2025, the ICC issued an order approving Ameren Illinois’ 2024 electric distribution service revenue requirement reconciliation adjustment filing. In March 2026, Ameren Illinois filed an appeal of the December 2025 order with the Illinois Appellate Court for the Fifth Judicial District and withdrew the appeal in July 2026 as a result of the appellate court decision in the MYRP proceeding discussed above.
2025 Electric Distribution Service Revenue Requirement Reconciliation Adjustment Review
In April 2026, Ameren Illinois filed a reconciliation adjustment to its 2025 electric distribution service revenue requirement with the ICC. In August 2026, Ameren Illinois updated its reconciliation adjustment, requesting recovery of $28 million. The adjustment reflects Ameren Illinois’ actual 2025 recoverable costs, 2025 year-end rate base, and a capital structure composed of 50 % common equity. The ICC staff has not objected to Ameren Illinois’ updated reconciliation adjustment. In November 2026, the administrative law judges issued a proposed order consistent with Ameren Illinois’ request. An ICC decision is required by December 2026, and any approved adjustment would be collected from customers in 2027.
Electric Energy Efficiency Plan
Pursuant to the CRGA, the annual spending cap for energy-efficiency investments increased for 2027, 2028, and 2029. As a result, in May 2026, Ameren Illinois filed an electric energy efficiency plan with the ICC, which includes annual investments in electric energy-efficiency programs up to $192 million, $239 million, and $276 million for 2027, 2028, and 2029, respectively. 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 Ameren Illinois’ investments in electric energy-efficiency programs. A decision by the ICC in this proceeding is expected in November 2026.
2025 Natural Gas Delivery Service Rate Order
In November 2025, the ICC issued an order in Ameren Illinois’ January 2025 natural gas delivery service regulatory rate review, which resulted in an increase to Ameren Illinois’ annual revenues for natural gas delivery service of $79 million based on a 9.60 % ROE, a capital structure composed of 50 % common equity, a 2026 future test year, and a rate base of $3.2 billion. The order reflected a reduction of $75 million of planned distribution and transmission capital investments included in Ameren Illinois’ future test year request. The new rates became effective in December 2025.
In January 2026, Ameren Illinois filed an appeal of the ICC’s November 2025 order to the Illinois Appellate Court for the Fifth Judicial District. The appeal challenged the inclusion of the non-service cost component of the net periodic benefit income related to other postretirement benefits in the annual revenue requirement and the $75 million reduction of planned capital investments, among other things. The court is under no deadline to address the appeal, and Ameren Illinois cannot predict the ultimate outcome of the appeal.
QIP Reconciliation Hearing
Pursuant to Illinois law, 2014 was the first year of the QIP. In 2021, Ameren Illinois filed a request with the ICC to initiate a reconciliation proceeding of natural gas capital investments recovered under the QIP rider during 2020. Ameren Illinois recovered similar investments in each of the 2014 to 2019 annual reconciliations. 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 $30 million in natural gas capital investments as imprudent, unsupported, or ineligible to be recovered through the QIP, resulting in a potential over-recovery of an immaterial amount by Ameren Illinois in 2020. In 2023, and again in 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 is within the rate increase limitations allowed by law. The ICC is under no deadline to issue an order in this proceeding. In addition, the 2021 through 2023 reconciliation proceedings are still ongoing. Ameren Illinois included $529 million of eligible natural gas capital investments in the QIP from 2021 to 2023. Ameren Illinois cannot predict the ultimate outcome of these regulatory proceedings.
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Federal
Transmission Rate Incentives
In 2024, the MISO approved a first set of second tranche projects related to its preliminary long-range transmission planning roadmap of projects through 2039. In 2026, the MISO awarded three competitive bid projects to ATXI and other joint owners that represent a total estimated investment of approximately $1.2 billion for ATXI, based on the MISO’s cost estimate. In August 2026, the FERC approved transmission rate incentives relating to two of these competitive bid projects. The incentives will allow construction work in progress to be included in rate base, thereby improving the timeliness of cash recovery, and will allow recovery of prudently incurred costs, subject to FERC approval, for any portion of the projects if they are abandoned for reasons beyond the control of ATXI. Since construction work in progress will be included in rate base and earn a return, ATXI will not capitalize allowance for funds used during construction on these projects.
FERC ROE 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 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 June 2026, the United States Court of Appeals for the District of Columbia Circuit dismissed and denied various appeals of the October 2024 FERC order.
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.
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 to support the issuance of letters of credit for the borrowers. As of September 30, 2026, 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 $2.7 billion, and does not include Ameren’s forward equity sale agreements discussed below in Note 4 – Long-term Debt and Equity Financings. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of September 30, 2026. As of September 30, 2026, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were 61 %, 49 %, and 46 % for Ameren, Ameren Missouri, and Ameren Illinois, respectively.
The following table presents commercial paper outstanding, net of issuance discounts, as of September 30, 2026, and December 31, 2025. There were no borrowings outstanding under the Credit Agreements as of September 30, 2026, or December 31, 2025.
| September 30, 2026 | December 31, 2025 | |||||||||||||
| Ameren (parent) | $ | $ | ||||||||||||
| Ameren Missouri | ||||||||||||||
| Ameren Illinois | ||||||||||||||
| Ameren consolidated | $ | $ | ||||||||||||
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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, 2026 and 2025:
| Ameren (parent) | Ameren Missouri | Ameren Illinois | Ameren Consolidated | ||||||||||||||||||||||||||
| 2026 | |||||||||||||||||||||||||||||
| Average daily amount outstanding | $ | $ | $ | $ | |||||||||||||||||||||||||
| Weighted-average interest rate | % | % | % | % | |||||||||||||||||||||||||
Peak amount outstanding during period(a) | $ | $ | $ | $ | |||||||||||||||||||||||||
| Peak interest rate | % | % | % | % | |||||||||||||||||||||||||
| 2025 | |||||||||||||||||||||||||||||
| Average daily amount outstanding | $ | $ | $ | $ | |||||||||||||||||||||||||
| Weighted-average interest rate | % | % | % | % | |||||||||||||||||||||||||
Peak amount outstanding during period(a) | $ | $ | $ | $ | |||||||||||||||||||||||||
| Peak interest rate | % | % | % | % | |||||||||||||||||||||||||
(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.
Separate from the Credit Agreements, Ameren and its utility subsidiaries have uncommitted letter of credit agreements totaling $200 million. These agreements may be used solely to support the issuance of letters of credit. As of September 30, 2026, Ameren and Ameren Missouri had $73 million and $50 million of letters of credit outstanding under these agreements, respectively.
Separate from the Credit Agreements and the uncommitted letter of credit agreements discussed above, Ameren Missouri has an uncommitted letter of credit agreement totaling $75 million. This agreement may be used solely to support the issuance of letters of credit. As of September 30, 2026, Ameren Missouri had $61 million of letters of credit outstanding under this agreement.
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, 2026 was 3.90 % and 3.89 %, respectively (2025 – 4.53 % and 4.56 %). 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, 2026 and 2025.
NOTE 4 – LONG-TERM DEBT AND EQUITY FINANCINGS
Ameren
For the three and nine months ended September 30, 2026, Ameren issued a total of 0.1 million and 0.3 million shares of common stock under its DRPlus and 401(k) plan, and received proceeds of $2 million and $24 million, respectively. As of September 30, 2026, Ameren had a receivable of $6 million related to issuances of common stock under its DRPlus and 401(k) plan. In addition, in the first quarter of 2026, Ameren issued 0.2 million shares of common stock valued at $25 million upon the settlement of stock-based compensation awards.
In May 2026, Ameren filed a Form S-3 registration statement with the SEC, registering the offering of 1.9 million shares of its common stock under the DRPlus, which expires in May 2029. Shares of common stock sold under the DRPlus are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated contracts.
In August 2026, Ameren, Ameren Missouri, and Ameren Illinois filed a Form S-3 shelf registration statement with the SEC, registering the issuance of an unspecified amount of certain types of securities. This registration statement expires in August 2029.
Ameren has entered into an equity distribution sales agreement pursuant to which Ameren may offer and sell from time to time its common stock through an ATM program, which includes the ability to enter into forward sale agreements. In August 2026, Ameren increased the amount of common stock available for sale under the ATM program by $2 billion to a total of $5 billion. There were no shares issued under the ATM program during the nine months ended September 30, 2026. As of September 30, 2026, Ameren had approximately $2 billion of common stock remaining available for sale under the ATM program.
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Forward sale agreements for 13 million shares outstanding under the ATM program as of September 30, 2026, can be settled at Ameren’s discretion on or prior to dates ranging from January 19, 2028, to March 8, 2028. The initial forward sale price for the agreements ranged from $104.39 to $112.91 , with an average initial forward sale price of $109.51 . Additionally in May 2025, Ameren entered into forward sale agreements separate from the ATM program with multiple counterparties relating to 6.4 million shares of common stock. The forward sale agreements can be settled at Ameren’s discretion on or prior to January 15, 2027, and the initial forward sale price under these agreements was $91.89 per share. 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. 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 or more than the spread on any day, the interest rate factor will result in a reduction or an increase, respectively, 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, 2026, Ameren could have settled the forward sale agreements with physical delivery of 19.4 million shares of common stock to the respective counterparties in exchange for cash of $2 billion. Alternatively, the forward sale agreements could have also been net settled at September 30, 2026, with the counterparties delivering approximately $80 million of cash or approximately 0.8 million shares of common stock to Ameren. In connection with the forward sale agreements outstanding at September 30, 2026, the various counterparties, or their affiliates, borrowed from third parties and sold 19.4 million shares of common stock. The gross sales price of these shares totaled $2 billion. Ameren does not receive any proceeds from such sales of borrowed shares. The forward sale agreements have been classified as equity transactions.
In October 2026, Ameren entered into forward sale agreements under the ATM program for 2.1 million shares of common stock. The October 2026 forward sales can be settled at Ameren’s discretion in or prior to March 2028. The average forward sale price was initially $99.59 for the October 2026 forward sale agreements.
In March 2026, Ameren (parent) issued $400 million of 5.00 % senior unsecured notes due May 2036, with interest payable semiannually on May 15 and November 15 of each year, beginning November 15, 2026. Net proceeds from this issuance were used to repay a portion of Ameren’s short-term debt, including short-term debt incurred to refinance $350 million of 3.65 % senior unsecured notes that matured in February 2026.
In September 2026, Ameren (parent) issued $900 million of junior subordinated notes due March 2057, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2027. Net proceeds from this issuance were used for general corporate purposes, including repayment of short-term debt. The junior subordinated notes will initially pay interest at a fixed annual rate of 6.45 % until March 15, 2032. After that date, the interest rate will be reset every five years to the applicable five-year United States plus 1.868 %, subject to a minimum rate of 6.45 %.
In 2026, Ameren (parent) purchased first mortgage bonds issued by Ameren Missouri for $16 million. On a consolidated basis, Ameren (parent)’s repurchase of these first mortgage bonds was accounted for as a debt extinguishment and resulted in a pre-tax gain of $4 million, which is reflected in “Other Income, Net” on Ameren’s consolidated statement of income.
Ameren Missouri
In February 2026, Ameren Missouri issued $450 million of 4.80 % first mortgage bonds due March 2036 and $450 million of 5.55 % first mortgage bonds due March 2056. Interest is payable semiannually for both issuances on March 15 and September 15 of each year, beginning September 15, 2026. Net proceeds from the February 2026 issuances were used for capital expenditures and to repay short-term debt.
In June 2026, Ameren Missouri issued $500 million of 5.75 % first mortgage bonds due September 2056, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2027. Net proceeds from this issuance were used to repay short-term debt.
Ameren Missouri received capital contributions totaling $125 million and $550 million, respectively, during the three and nine months ended September 30, 2026.
Ameren Illinois
In August 2026, Ameren Illinois issued $400 million of 5.50 % first mortgage bonds due September 2036, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2027. Net proceeds from this issuance were used to repay short-term debt.
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ATXI
In August 2026, pursuant to a note purchase agreement, ATXI issued $140 million of 5.83 % senior unsecured notes due August 2041, with interest payable semiannually on February 6 and August 6 of each year, beginning February 6, 2027, through a private placement offering exempt from registration under the Securities Act of 1933, as amended. Net proceeds from this issuance were used to repay short-term debt.
In August 2026, pursuant to a note purchase agreement, ATXI agreed to issue $160 million of 6.24 % senior unsecured notes due January 2054, with interest payable semiannually on January 28 and July 28 of each year, beginning July 28, 2027, through a private placement offering exempt from registration under the Securities Act of 1933, as amended. ATXI expects to issue the notes and receive the proceeds in January 2027, which will be used to repay short-term debt.
Indenture Provisions and Other Covenants
See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for a description of our indenture provisions and other covenants, as well as restrictions on the payment of dividends. At September 30, 2026, the Ameren Companies were in compliance with the provisions and covenants contained in their indentures and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreements.
Off-balance-sheet Arrangements
At September 30, 2026, none of the Ameren Companies had any material off-balance-sheet financing arrangements, other than their investment in unconsolidated variable interest entities, letters of credit, and the forward sale agreements relating to common stock. See Note 1 – Summary of Significant Accounting Policies for further detail concerning variable interest entities.
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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, 2026 and 2025:
| Three Months | Nine Months | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Ameren: | |||||||||||||||||||||||
Allowance for equity funds used during construction | $ | $ | $ | $ | |||||||||||||||||||
Other interest income | |||||||||||||||||||||||
Non-service cost components of net periodic benefit income(a) | |||||||||||||||||||||||
Miscellaneous income | |||||||||||||||||||||||
Gain on extinguishment of debt(b) | |||||||||||||||||||||||
| Earnings (losses) related to equity method investments | ( | ( | |||||||||||||||||||||
Donations | ( | ( | ( | ( | |||||||||||||||||||
Miscellaneous expense | ( | ( | ( | ( | |||||||||||||||||||
| Total Other Income, Net | $ | $ | $ | $ | |||||||||||||||||||
| Ameren Missouri: | |||||||||||||||||||||||
Allowance for equity funds used during construction | $ | $ | $ | $ | |||||||||||||||||||
Other interest income | |||||||||||||||||||||||
Non-service cost components of net periodic benefit income(a) | |||||||||||||||||||||||
Miscellaneous income | |||||||||||||||||||||||
Donations | ( | ( | ( | ( | |||||||||||||||||||
Miscellaneous expense | ( | ( | ( | ( | |||||||||||||||||||
| Total Other Income, Net | $ | $ | $ | $ | |||||||||||||||||||
| Ameren Illinois: | |||||||||||||||||||||||
Allowance for equity funds used during construction | $ | $ | $ | $ | |||||||||||||||||||
| Other interest income | |||||||||||||||||||||||
Non-service cost components of net periodic benefit income | |||||||||||||||||||||||
Miscellaneous income | |||||||||||||||||||||||
Donations | ( | ( | ( | ||||||||||||||||||||
| Miscellaneous expense | ( | ( | ( | ( | |||||||||||||||||||
| Total Other Income, Net | $ | $ | $ | $ | |||||||||||||||||||
(a)For the three and nine months ended September 30, 2026, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $(19 ) million and $(59 ) 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 $(9 ) million and $(41 ) million, respectively, for the three and nine months ended September 30, 2025. See Note 11 – Retirement Benefits for additional information.
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NOTE 6 – DERIVATIVE FINANCIAL INSTRUMENTS
We use derivatives to manage the risk of changes in market prices for natural gas, power, and interest rates, 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 that differ from the cost of this commodity in inventory;
•actual cash outlays for interest expense and the purchase of commodities that differ from anticipated cash outlays; and
•actual off-system sales revenues that differ from anticipated revenues.
The derivatives that we use to hedge these risks are governed by our risk management policies for forward contracts, futures, options, and swaps. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. The goal of the hedging program is generally to mitigate financial risks while ensuring that sufficient volumes are available to meet our requirements. Contracts we enter into as part of our risk management program may be settled financially, settled by physical delivery, or net settled with the counterparty.
All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. Many of our physical contracts, such as our purchased power contracts, qualify for the NPNS exception to derivative accounting rules. The revenue or expense on NPNS contracts is recognized at the contract price upon physical delivery. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting.
Ameren (parent) entered into interest rate swaps to hedge interest rate risk on certain forecasted interest payments associated with debt issuances in 2026 and 2027. The interest rate swaps are designated as cash flow hedges and the corresponding changes in fair value each period are initially recorded on the balance sheet in “Accumulated other comprehensive income (loss)” and reclassified into earnings when the debt is issued and the corresponding interest payments affect earnings during the debt term. As of September 30, 2026, and December 31, 2025, Ameren had unsettled interest rate swaps with notional amounts of $490 million and $820 million, respectively. Ameren recorded unrealized net gains (losses), net of income taxes (benefit), on the change in fair value of interest rate swaps of $34 million and $38 million for the three and nine months ended September 30, 2026 and less than $(1 ) million and $(6 ) million for the three and nine months ended September 30, 2025 to “Accumulated other comprehensive income (loss).” The gains (losses) reclassified out of “Accumulated other comprehensive income (loss)” to “Interest Charges” for the three and nine months ended September 30, 2026 were immaterial.
The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of September 30, 2026, and December 31, 2025. As of September 30, 2026, these contracts extended through October 2029, October 2032, and May 2032 for fuel oils, natural gas, and power, respectively.
| Quantity (in millions, except as indicated) | ||||||||||||||||||||
| September 30, 2026 | December 31, 2025 | |||||||||||||||||||
| Commodity | Ameren Missouri | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois | Ameren | ||||||||||||||
| Fuel oils (in gallons) | ||||||||||||||||||||
| Natural gas (in MMBtu) | ||||||||||||||||||||
| Power (in MWhs) | ||||||||||||||||||||
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The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments because all qualify for regulatory deferral, as of September 30, 2026, and December 31, 2025:
| September 30, 2026 | December 31, 2025 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commodity | Balance Sheet Location | Ameren Missouri | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois | Ameren | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fuel oils | Other current assets | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other assets | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Natural gas | Other current assets | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other assets | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Power | Other current assets | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other assets | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total assets | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fuel oils | Other current liabilities | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other deferred credits and liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Natural gas | Mark-to-market derivative liabilities | (a) | (a) | (a) | (a) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other current liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other deferred credits and liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Power | Mark-to-market derivative liabilities | (a) | (a) | (a) | (a) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other current liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other deferred credits and liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total liabilities | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||
(a) Balance sheet line item not applicable to registrant.
The Ameren Companies elect to present the fair value amounts of derivative assets and derivative liabilities subject to an enforceable master netting arrangement or similar agreement at the gross amounts on the balance sheet. However, if the gross amounts recognized on the balance sheet were netted with derivative instruments and cash collateral received or posted, the net amounts would not be materially different from the gross amounts at September 30, 2026, and December 31, 2025.
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, 2026, if counterparty groups were to fail completely to perform on contracts, the Ameren Companies’ maximum exposure related to derivative assets 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. As of September 30, 2026, the aggregate fair value of derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require were each immaterial to Ameren, Ameren Missouri, and Ameren Illinois.
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.
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, 2026 or 2025. At September 30, 2026, and December 31, 2025, the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois.
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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, 2026, and December 31, 2025:
| September 30, 2026 | December 31, 2025 | |||||||||||||||||||||||||||||||||||||
| Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||||||||||||
| Assets: | ||||||||||||||||||||||||||||||||||||||
| Ameren Missouri | ||||||||||||||||||||||||||||||||||||||
| Derivative assets – commodity contracts: | ||||||||||||||||||||||||||||||||||||||
| Fuel oils | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Natural gas | ||||||||||||||||||||||||||||||||||||||
| Power | ||||||||||||||||||||||||||||||||||||||
| Total derivative assets – commodity contracts | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Nuclear decommissioning trust fund: | ||||||||||||||||||||||||||||||||||||||
| Equity securities: | ||||||||||||||||||||||||||||||||||||||
| U.S. large capitalization | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Debt securities: | ||||||||||||||||||||||||||||||||||||||
| U.S. Treasury and agency securities | ||||||||||||||||||||||||||||||||||||||
| Corporate bonds | ||||||||||||||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||||||||||||||
| Total nuclear decommissioning trust fund | $ | $ | $ | $ | (a) | $ | $ | $ | $ | (a) | ||||||||||||||||||||||||||||
| Total Ameren Missouri | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Ameren Illinois | ||||||||||||||||||||||||||||||||||||||
| Derivative assets – commodity contracts: | ||||||||||||||||||||||||||||||||||||||
| Natural gas | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Power | ||||||||||||||||||||||||||||||||||||||
| Total Ameren Illinois | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Ameren | ||||||||||||||||||||||||||||||||||||||
Derivative assets – commodity contracts(b) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
Nuclear decommissioning trust fund(c) | (a) | (a) | ||||||||||||||||||||||||||||||||||||
| Total Ameren | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Liabilities: | ||||||||||||||||||||||||||||||||||||||
| Ameren Missouri | ||||||||||||||||||||||||||||||||||||||
| Derivative liabilities – commodity contracts: | ||||||||||||||||||||||||||||||||||||||
| Fuel oils | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Natural gas | ||||||||||||||||||||||||||||||||||||||
| Power | ||||||||||||||||||||||||||||||||||||||
| Total Ameren Missouri | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Ameren Illinois | ||||||||||||||||||||||||||||||||||||||
| Derivative liabilities – commodity contracts: | ||||||||||||||||||||||||||||||||||||||
| Natural gas | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Power | ||||||||||||||||||||||||||||||||||||||
| Total Ameren Illinois | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
| Ameren | ||||||||||||||||||||||||||||||||||||||
Derivative liabilities – commodity contracts(b) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||
(a)Balance excludes $6 million and $12 million of cash and cash equivalents, receivables, payables, and accrued income, net, for September 30, 2026, and December 31, 2025, 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 natural gas 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, 2026:
| 2026 | |||||||||||
| Ameren Missouri | Ameren Illinois | Ameren | |||||||||
For the three months ended September 30: | |||||||||||
Beginning balance at July 1 | $ | $ | ( | $ | ( | ||||||
| Realized and unrealized gains/(losses) included in regulatory assets/liabilities | |||||||||||
| Settlements | ( | ( | |||||||||
Ending balance at September 30 | $ | $ | ( | $ | ( | ||||||
Change in unrealized gains/(losses) related to assets/liabilities held at September 30 | $ | $ | $ | ||||||||
For the nine months ended September 30: | |||||||||||
| Beginning balance at January 1 | $ | $ | ( | $ | ( | ||||||
| Realized and unrealized gains/(losses) included in regulatory assets/liabilities | |||||||||||
| Settlements | ( | ( | |||||||||
| Transfers out of Level 3 | |||||||||||
Ending balance at September 30 | $ | $ | ( | $ | ( | ||||||
Change in unrealized gains/(losses) related to assets/liabilities held at September 30 | $ | $ | $ | ||||||||
All gains or losses related to our Level 3 derivative commodity contracts are expected to be collected or refunded 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, 2026, and December 31, 2025:
| Fair Value | Weighted Average(b) | ||||||||||||||||||||||||||||
| Commodity | Assets | Liabilities | Valuation Technique(s) | Unobservable Input(a) | Range | ||||||||||||||||||||||||
| 2026 | Power(c) | $ | $ | ( | Discounted cash flow | Average forward peak and off-peak pricing – forwards/swaps ($/MWh) | |||||||||||||||||||||||
| Nodal basis ($/MWh) | ( | ( | |||||||||||||||||||||||||||
| 2025 | Power(c) | $ | $ | ( | Discounted cash flow | Average forward peak and off-peak pricing – forwards/swaps ($/MWh) | |||||||||||||||||||||||
| Nodal basis ($/MWh) | ( | ( | |||||||||||||||||||||||||||
(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, 2026, and December 31, 2025:
| Long-Term Debt (Including Current Portion): | Carrying Amount(a) | Fair Value | ||||||||||||||||||||||||
| Level 2 | Level 3 | Total | ||||||||||||||||||||||||
| September 30, 2026 | ||||||||||||||||||||||||||
Ameren(b) | $ | $ | $ | (c) | $ | |||||||||||||||||||||
Ameren Missouri(d) | ||||||||||||||||||||||||||
Ameren Illinois(d) | ||||||||||||||||||||||||||
| December 31, 2025 | ||||||||||||||||||||||||||
Ameren(b) | $ | $ | $ | (c) | $ | |||||||||||||||||||||
Ameren Missouri(d) | ||||||||||||||||||||||||||
Ameren Illinois(d) | ||||||||||||||||||||||||||
(a)Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $159 million, $72 million, and $57 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of September 30, 2026. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $136 million, $62 million, and $56 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2025.
(b)Amount excludes Ameren (parent)’s repurchase of Ameren Missouri’s senior secured notes and first mortgage bonds and Ameren Illinois’ first mortgage bonds that were accounted for as a debt extinguishment. See Note 4 – Long-term Debt and Equity Financings above and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for additional information.
(c)The Level 3 fair value amount consists of ATXI’s senior unsecured notes.
(d)Amount includes Ameren Missouri’s senior secured notes and first mortgage bonds and Ameren Illinois’ first mortgage bonds that were repurchased by Ameren (parent).
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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.
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 $32 million and $34 million, respectively, as of September 30, 2026, and $36 million and $38 million, respectively, as of December 31, 2025, related to Ameren Services’ allocated portion of Ameren’s pension and postretirement benefit plans.
Tax Allocation Agreement
See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for a discussion of the tax allocation agreement. The following table presents the affiliate balances related to income taxes for Ameren Missouri and Ameren Illinois as of September 30, 2026, and December 31, 2025:
| September 30, 2026 | December 31, 2025 | |||||||||||||||||||
| Ameren Missouri | Ameren Illinois | Ameren Missouri | Ameren Illinois | |||||||||||||||||
Income taxes payable to parent(a) | $ | $ | $ | $ | ||||||||||||||||
Income taxes receivable from parent(b) | ||||||||||||||||||||
(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, 2026 and 2025:
| Three Months | Nine Months | |||||||||||||||||||||||||||||||
| Agreement | Income Statement Line Item | Ameren Missouri | Ameren Illinois | Ameren Missouri | Ameren Illinois | |||||||||||||||||||||||||||
| Ameren Missouri and Ameren Illinois | Operating Revenues | 2026 | $ | $ | (a) | $ | $ | (a) | ||||||||||||||||||||||||
rent and facility services | 2025 | (a) | ||||||||||||||||||||||||||||||
| Ameren Illinois interconnection agreement | Operating Revenues | 2026 | (b) | (b) | ||||||||||||||||||||||||||||
| with Ameren Missouri | 2025 | (b) | (a) | (b) | (a) | |||||||||||||||||||||||||||
| Ameren Missouri and Ameren Illinois miscellaneous | Operating Revenues | 2026 | $ | (a) | $ | $ | $ | |||||||||||||||||||||||||
| support services | 2025 | (a) | ||||||||||||||||||||||||||||||
| Total Operating Revenues | 2026 | $ | $ | $ | $ | |||||||||||||||||||||||||||
| 2025 | (a) | |||||||||||||||||||||||||||||||
| Ameren Missouri and Ameren Illinois | Purchased Power | 2026 | $ | $ | (a) | $ | $ | |||||||||||||||||||||||||
| transmission services from ATXI | 2025 | |||||||||||||||||||||||||||||||
| Ameren Missouri interconnection agreement | Purchased Power | 2026 | (b) | (b) | ||||||||||||||||||||||||||||
| with Ameren Illinois | 2025 | (a) | (b) | (a) | (b) | |||||||||||||||||||||||||||
| Total Purchased Power | 2026 | $ | $ | (a) | $ | $ | ||||||||||||||||||||||||||
| 2025 | ||||||||||||||||||||||||||||||||
| Ameren Missouri and Ameren Illinois | Other Operations and Maintenance | 2026 | $ | $ | $ | $ | ||||||||||||||||||||||||||
rent and facility services | 2025 | (a) | (a) | (a) | ||||||||||||||||||||||||||||
| Ameren Services support services | Other Operations and Maintenance | 2026 | $ | $ | $ | $ | ||||||||||||||||||||||||||
agreement | 2025 | |||||||||||||||||||||||||||||||
| Total Other Operations and | 2026 | $ | $ | $ | $ | |||||||||||||||||||||||||||
| Maintenance | 2025 | |||||||||||||||||||||||||||||||
| Money pool interest (advances) | (Interest Charges)/Other Income, Net | 2026 | $ | (a) | $ | (a) | $ | (a) | $ | (a) | ||||||||||||||||||||||
| 2025 | (a) | (a) | (a) | (a) | ||||||||||||||||||||||||||||
| Long-term debt, net - related parties | (Interest Charges) | 2026 | $ | ( | $ | (a) | $ | ( | $ | (a) | ||||||||||||||||||||||
| 2025 | ( | (a) | ( | (a) | ||||||||||||||||||||||||||||
(a)Amount less than $1
(b)Not applicable.
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 regulate air emissions; protect water bodies; regulate the handling and disposal of hazardous substances and waste materials; establish siting and land use requirements; and protect against 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 and hazardous materials require release prevention plans and emergency response procedures.
Environmental regulations impact the electric utility industry, and compliance obligations could be costly for Ameren Missouri, which operates coal-fired and natural gas-fired energy centers. Compliance obligations under the Clean Air Act stem from a variety of programs
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including the NSPS, the MATS, emission allowance programs, the CSAPR, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO2, particulate matter, NOx, mercury, toxic metals and acid gases, and CO2 emissions, although the scope of covered pollutants can change. To the extent our operations impact surface water bodies, including wetlands, the Clean Water Act requires permitting as well as evaluation of the ecological and biological impact of those operations. Implementation of requirements under the Clean Air Act and the Clean Water Act typically occurs through the issuance of permits by state regulators or resource agencies, and capital expenditures associated with compliance could be significant. The management and disposal of coal ash from our coal-fired energy centers must comply with federal regulations known as the CCR Rule issued under the Resource Conservation and Recovery Act and require the closure of surface impoundments at our coal-fired energy centers along with groundwater monitoring requirements and the implementation of corrective measures if necessary. The combined effects of compliance with existing and future environmental regulations and permitting could result in significant capital expenditures, increased operating costs, and the potential for 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 Energy Center has curtailed nighttime operations from April through October to limit impacts on protected species during the critical biological season. Ameren Missouri does not anticipate these nighttime operating curtailments will have a material impact on its results of operations, financial position, or liquidity. In March 2026, Ameren Missouri submitted an application to the United States Fish and Wildlife Service for a new 30-year federal permit that allows for the continued operation of the High Prairie Energy Center. Ameren Missouri’s current permit expires in May 2027. Ameren and Ameren Missouri cannot predict when, or if, the permit application will be approved by the United States Fish and Wildlife Service.
Ameren and Ameren Missouri anticipate they may need to make estimated capital expenditures of $50 80
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 could revise all or part of such federal regulations.
Clean Air Act
Federal and state laws, including the CSAPR, regulate emissions of SO2 and NOx through the reduction of emissions at their source and the use and retirement of emission allowances available for state budgets. In 2022, the EPA proposed the Good Neighbor Rule to reduce the transport of ozone from power plants by reducing the amount of CSAPR NOx allowances available for compliance. In January 2026, the EPA issued a proposed rule to reconsider the Good Neighbor Rule which, if finalized as proposed, would resolve underlying litigation involving numerous states including Missouri. Ameren Missouri complies with the current CSAPR requirements by minimizing emissions with low-sulfur coal, operation of two scrubbers at its Sioux Energy Center, and optimization of existing NOx air pollution control equipment. If a final rule is issued similar to the proposed rule, Ameren Missouri would not expect additional NOx controls at its coal-fired energy centers to be necessary.
CO2 Emissions Standards
In 2024, the EPA issued a final rule that set CO2 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. In September 2026, the EPA issued a final rule partially repealing the 2024 rule, including provisions related to existing power plants and certain carbon capture standards on new natural gas-fired power plants. Also in September 2026, the EPA issued a proposed rule to repeal all remaining greenhouse gas emissions standards for fossil fuel-fired power plants, including the remaining provisions under the 2024 rule. Previously, in February 2026, the EPA issued a final rule to rescind its 2009 Greenhouse Gas Endangerment Finding, which was the basis for implementing greenhouse gas emissions standards. Litigation regarding the rescission of the Endangerment Finding is ongoing and litigation regarding the EPA’s partial repeal of the 2024 final rule is expected. Ameren and Ameren Missouri are assessing the final rules and, at this time, cannot predict the impacts of the final rules on their results of operations, financial position, and liquidity.
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MATS
In February 2026, the EPA issued a final rule repealing a 2024 rule that had revised the MATS and established more stringent standards for emissions of particulate matter and mercury and required the use of continuous emissions monitoring systems. As a result of the repeal, the 2024 rule will not impact Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity.
NSPS
In January 2026, the EPA issued a final rule that established NOx emission standards for several subcategories of stationary CTs that began construction after mid-December 2024, based on size, utilization, design efficiency, and fuel type. Ameren and Ameren Missouri do not expect the final rule to materially impact their results of operations, financial position, and liquidity.
Clean Water Act
All of Ameren Missouri’s coal-fired and nuclear energy centers are subject to Clean Water Act requirements to 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. Cooling water intake requirements 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 are in the process of renewal.
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 two surface impoundments in process at its retired Meramec Energy Center as a part of the construction of the Castle Bluff Natural Gas Project. Ameren Missouri’s CCR management compliance plan includes installation of groundwater monitoring equipment and groundwater treatment facilities. In 2024, the EPA revised the CCR Rule to include certain active and inactive CCR surface impoundments and disposal units not previously included in the 2015 CCR Rule. Ameren and Ameren Missouri recorded AROs of $57
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, 2026, Ameren Illinois has remediated the majority of the 44 former MGP sites that it is responsible for in Illinois with an estimated remaining obligation primarily related to three of these former MGP sites at $45 million to $90 million. Ameren and Ameren Illinois recorded a liability of $45
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. Such historical practices may result in future environmental commitments, including additional or more stringent cleanup standards. We are unable to determine whether such historical practices will affect our results of operations, financial position, or liquidity.
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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. 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 September 2026 and resulted in an immaterial change in the ARO balance as of September 30, 2026. The updated cost study proposed to maintain the annual customer contributions for funding the Callaway Energy Center decommissioning costs at zero consistent with a May 2025 MoPSC order, as the trust fund level exceeded the estimated present value of future decommissioning costs. See Note 13 – Supplemental Information for more information on Ameren Missouri’s AROs.
Insurance
The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at September 30, 2026:
| 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, 2026 | $ | $ | ||||||||||||||
| Pool participation | (a) | (a) | (b) | ||||||||||||||
| $ | (c) | $ | |||||||||||||||
| Property damage: | |||||||||||||||||
| NEIL and EMANI | April 1, 2026 | $ | (d) | $ | (e) | ||||||||||||
| Accidental outage: | |||||||||||||||||
| NEIL | April 1, 2026 | $ | (f) | $ | (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 $25 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 retrospective 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, or are not covered by insurance, or if coverage is unavailable, Ameren Missouri is at risk for any uninsured losses. If a serious nuclear incident were to occur, it could have a material adverse effect on Ameren’s and Ameren Missouri’s results of operations, financial position, or liquidity.
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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, 2026 and 2025:
| Pension Benefits | Postretirement Benefits | |||||||||||||||||||||||||||||||||||||||||||||||||
| Three Months | Nine Months | Three Months | Nine Months | |||||||||||||||||||||||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||||||||||||||||||||||
Service cost(a) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||
| Non-service cost components: | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Interest cost | ||||||||||||||||||||||||||||||||||||||||||||||||||
Expected return on plan assets(b) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||||||
Amortization of:(b) | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Prior service cost (credit) | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||
| Actuarial (gain) loss | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||
Total non-service cost components(c) | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||||||||||
Net periodic benefit cost (income)(d) | $ | $ | ( | $ | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||||||||||||
(a)Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income.
(b)Prior service cost (credit) 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 subject to amortization are amortized over 10 4
(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 customer 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, 2026 and 2025:
| Pension Benefits | Postretirement Benefits | |||||||||||||||||||||||||||||||||||||||||||||||||
| Three Months | Nine Months | Three Months | Nine Months | |||||||||||||||||||||||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||||||||||||||||||||||
Ameren Missouri(a) | $ | $ | ( | $ | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||||||||||||
| Ameren Illinois | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||
| Other | ( | ( | (b) | (b) | (b) | (b) | ||||||||||||||||||||||||||||||||||||||||||||
Ameren(a) | $ | $ | ( | $ | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||||||||||||
(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 customer rates.
(b)Amount less than $1
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NOTE 12 – INCOME TAXES
The following table presents the principal reasons for the difference between the effective income tax expense and rate and the federal statutory corporate income tax expense and rate for the three and nine months ended September 30, 2026 and 2025:
| Three Months | Three Months | Nine Months | Nine Months | |||||||||||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||||||||||||||
| Amount | Effective Tax Rate | Amount | Effective Tax Rate | Amount | Effective Tax Rate | Amount | Effective Tax Rate | |||||||||||||||||||||||||||||||
| Ameren | ||||||||||||||||||||||||||||||||||||||
| $ | % | $ | % | $ | % | $ | % | |||||||||||||||||||||||||||||||
State and local taxes, net of federal income tax(a) | ||||||||||||||||||||||||||||||||||||||
| Tax credits | ||||||||||||||||||||||||||||||||||||||
Renewable energy tax credits(b) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Other | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Nontaxable or nondeductible items | ( | ( | ||||||||||||||||||||||||||||||||||||
| Other adjustments | ||||||||||||||||||||||||||||||||||||||
Amortization of excess deferred income taxes(c) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
Revaluation of excess deferred income taxes(d) | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||
| Depreciation differences | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Effective income tax expense and rate | $ | % | $ | % | $ | % | $ | % | ||||||||||||||||||||||||||||||
| Ameren Missouri | ||||||||||||||||||||||||||||||||||||||
| Federal statutory corporate income tax expense and rate | $ | % | $ | % | $ | % | $ | % | ||||||||||||||||||||||||||||||
State and local taxes, net of federal income tax(a) | ||||||||||||||||||||||||||||||||||||||
| Tax credits | ||||||||||||||||||||||||||||||||||||||
Renewable energy tax credits(b) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Other | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Other adjustments | ||||||||||||||||||||||||||||||||||||||
Amortization of excess deferred income taxes(c) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Depreciation differences | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
| Effective income tax expense (benefit) and rate | $ | % | $ | % | $ | % | $ | % | ||||||||||||||||||||||||||||||
| Ameren Illinois | ||||||||||||||||||||||||||||||||||||||
| Federal statutory corporate income tax expense and rate | $ | % | $ | % | $ | % | $ | % | ||||||||||||||||||||||||||||||
State and local taxes, net of federal income tax(a) | ||||||||||||||||||||||||||||||||||||||
| Nontaxable or nondeductible items | ( | |||||||||||||||||||||||||||||||||||||
| Other adjustments | ||||||||||||||||||||||||||||||||||||||
Amortization of excess deferred income taxes(c) | ( | ( | ( | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||
Revaluation of excess deferred income taxes(d) | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||
| Depreciation differences | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||
| Effective income tax expense and rate | $ | % | $ | % | $ | % | $ | % | ||||||||||||||||||||||||||||||
(a)State taxes in Missouri and Illinois made up the majority of the tax effect in this category for Ameren, Ameren Missouri, and Ameren Illinois.
(b)The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM. The benefit of the credits associated with the production and investment tax credit tracker will be refunded to customers based on MoPSC approval in a regulatory rate review.
(c)Reflects the amortization of a regulatory liability resulting from the revaluation of accumulated deferred income taxes subject to regulatory ratemaking, which are being refunded to customers.
(d)In 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 applicable to the ratemaking treatment 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. In 2025, the FERC issued an order reflecting implementation of the rules for the other taxpayer who had a similar fact pattern as Ameren Illinois and ATXI. Accordingly, in the third quarter of 2025, Ameren and Ameren Illinois decreased income tax expense by $48 million and $23 million, respectively, to reflect the revaluation of excess deferred income tax regulatory liabilities resulting from TCJA for FERC-regulated jurisdictions pursuant to IRS guidance and a 2025 FERC order.
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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, 2026, and December 31, 2025:
| September 30, 2026 | December 31, 2025 | |||||||||||||||||||||||||||||||||||||
| Ameren | Ameren Missouri | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois | |||||||||||||||||||||||||||||||||
| “Cash and cash equivalents” | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
| Restricted cash included in “Other current assets” | ||||||||||||||||||||||||||||||||||||||
| Restricted cash included in “Other assets” | ||||||||||||||||||||||||||||||||||||||
| Restricted cash included in “Nuclear decommissioning trust fund” | ||||||||||||||||||||||||||||||||||||||
| Total cash, cash equivalents, and restricted cash | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||
Restricted cash included in “Other current assets” represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees on Ameren’s, Ameren Missouri’s, and Ameren Illinois’ balance sheets, funds held in an escrow account for programs established as a result of a 2024 court order resolving outstanding claims in the NSR and Clean Air Act litigation on Ameren’s and Ameren Missouri’s balance sheets, and AMF’s restricted cash for payments for securitized utility tariff bonds on Ameren’s and Ameren Missouri’s balance sheets. 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, 2026, and December 31, 2025, Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of $65 47
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, 2026 and 2025:
| Three Months | Nine Months | ||||||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||||||||
| Ameren: | |||||||||||||||||||||||||||||
| Beginning of period | $ | $ | $ | $ | |||||||||||||||||||||||||
| Bad debt expense | |||||||||||||||||||||||||||||
Charged to other accounts(a) | |||||||||||||||||||||||||||||
| Net write-offs | ( | ( | ( | ( | |||||||||||||||||||||||||
| End of period | $ | $ | $ | $ | |||||||||||||||||||||||||
| Ameren Missouri: | |||||||||||||||||||||||||||||
| Beginning of period | $ | $ | $ | $ | |||||||||||||||||||||||||
| Bad debt expense | |||||||||||||||||||||||||||||
| Net write-offs | ( | ( | ( | ( | |||||||||||||||||||||||||
| End of period | $ | $ | $ | $ | |||||||||||||||||||||||||
Ameren Illinois:(b) | |||||||||||||||||||||||||||||
| Beginning of period | $ | $ | $ | $ | |||||||||||||||||||||||||
| Bad debt expense | |||||||||||||||||||||||||||||
Charged to other accounts(a) | |||||||||||||||||||||||||||||
| Net write-offs | ( | ( | ( | ( | |||||||||||||||||||||||||
| End of period | $ | $ | $ | $ | |||||||||||||||||||||||||
(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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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, 2026 and 2025:
| September 30, 2026 | September 30, 2025 | ||||||||||||||||||||||||||||
| Ameren | Ameren Missouri | Ameren Illinois | Ameren | Ameren Missouri | Ameren Illinois | ||||||||||||||||||||||||
| Investing: | |||||||||||||||||||||||||||||
| Accrued capital expenditures, including nuclear fuel expenditures | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||
| Net realized and unrealized gain – nuclear decommissioning trust fund | |||||||||||||||||||||||||||||
| Financing: | |||||||||||||||||||||||||||||
| Issuance of common stock for stock-based compensation | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||
| Issuance of common stock under the DRPlus | |||||||||||||||||||||||||||||
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, 2026:
| Ameren Missouri | Ameren Illinois | Ameren | ||||||||||||||||||
Balance at December 31, 2025 | $ | (a) | $ | (b) | $ | (a) | ||||||||||||||
| Liabilities incurred | ||||||||||||||||||||
| Liabilities settled | ( | (c) | ( | |||||||||||||||||
| Accretion | (d) | (c) | (d) | |||||||||||||||||
| Change in estimates | ( | ( | ||||||||||||||||||
Balance at September 30, 2026 | $ | (a) | $ | (b) | $ | (a) | ||||||||||||||
(a)Balance included $3 million and $5 million in “Other current liabilities” on the balance sheet as of September 30, 2026, and December 31, 2025, respectively.
(b)Included in “Other deferred credits and liabilities” on the balance sheet.
(c)Amount less than $1
(d)Accretion expense attributable to Ameren Missouri was recorded as a decrease to regulatory liabilities.
Deferred Compensation
At September 30, 2026, and December 31, 2025, the present value of benefits to be paid for deferred compensation obligations was $80 million and $79 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet.
Operating Revenues
As of September 30, 2026 and 2025, 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
| Three Months | Nine Months | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Ameren Missouri | $ | $ | $ | $ | |||||||||||||||||||
| Ameren Illinois | |||||||||||||||||||||||
| Ameren | $ | $ | $ | $ | |||||||||||||||||||
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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, 2026 and 2025:
| Three Months | Nine Months | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Weighted-average Common Shares Outstanding – Basic | |||||||||||||||||||||||
| Assumed settlement of performance share units and restricted stock units | |||||||||||||||||||||||
| Dilutive effect of forward sale agreements | |||||||||||||||||||||||
Weighted-average Common Shares Outstanding – Diluted(a) | |||||||||||||||||||||||
(a)There was an immaterial 6.0 million and 12.3 million shares for the three and nine months ended September 30, 2026 and an immaterial
NOTE 14 – SEGMENT INFORMATION
The following tables present revenues, specified items reflected in 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, 2026 and 2025. 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
| Reportable Segments | |||||||||||||||||||||||||||||||||||||||||
| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Other | Intersegment Eliminations | Ameren | |||||||||||||||||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | $ | — | $ | — | $ | ||||||||||||||||||||||||||||||||
| Intersegment revenues | — | ( | — | ||||||||||||||||||||||||||||||||||||||
| Revenue | — | ( | |||||||||||||||||||||||||||||||||||||||
Fuel and purchased power(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other income (expense), net | ( | ||||||||||||||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | $ | $ | ( | $ | $ | ( | $ | — | $ | |||||||||||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||||||
| Capital expenditures | |||||||||||||||||||||||||||||||||||||||||
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| Reportable Segments | |||||||||||||||||||||||||||||||||||||||||
| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Other | Intersegment Eliminations | Ameren | |||||||||||||||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | $ | — | $ | — | $ | ||||||||||||||||||||||||||||||||
| Intersegment revenues | — | ( | — | ||||||||||||||||||||||||||||||||||||||
| Revenue | — | ( | |||||||||||||||||||||||||||||||||||||||
Fuel and purchased power(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other income (expense), net | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | $ | $ | ( | $ | (b) | $ | ( | $ | — | $ | ||||||||||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||||||
| Capital expenditures | |||||||||||||||||||||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | $ | — | $ | — | $ | ||||||||||||||||||||||||||||||||
| Intersegment revenues | — | ( | — | ||||||||||||||||||||||||||||||||||||||
| Revenue | — | ( | |||||||||||||||||||||||||||||||||||||||
Fuel and purchased power(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other income (expense), net | ( | ||||||||||||||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | $ | $ | $ | $ | ( | $ | — | $ | ||||||||||||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||||||
| Capital expenditures | |||||||||||||||||||||||||||||||||||||||||
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Table of Contents
| Reportable Segments | |||||||||||||||||||||||||||||||||||||||||
| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Other | Intersegment Eliminations | Ameren | |||||||||||||||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | $ | — | $ | — | $ | ||||||||||||||||||||||||||||||||
| Intersegment revenues | — | ( | — | ||||||||||||||||||||||||||||||||||||||
| Revenue | — | ( | |||||||||||||||||||||||||||||||||||||||
Fuel and purchased power(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Other income (expense), net | ( | ||||||||||||||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | ( | ( | ( | ||||||||||||||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | ( | ( | ||||||||||||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | $ | $ | $ | (b) | $ | ( | $ | — | $ | |||||||||||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||||||||||||
| Capital expenditures | |||||||||||||||||||||||||||||||||||||||||
(a)Significant segment expense that is regularly provided to the CODMs. Intersegment expenses are included within the amounts shown.
(b)Ameren Transmission earnings reflect an allocation of financing costs from Ameren (parent).
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Ameren Illinois
| Reportable Segments | |||||||||||||||||||||||||||||
| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Intersegment Eliminations | Ameren Illinois | |||||||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Intersegment revenues | ( | — | |||||||||||||||||||||||||||
| Revenue | ( | ||||||||||||||||||||||||||||
Purchased power(a) | ( | ( | |||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | — | ( | ||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other income, net | — | ||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | — | ( | |||||||||||||||||||||||||
| Net income (loss) available to common shareholder | ( | — | |||||||||||||||||||||||||||
| Interest income | — | ||||||||||||||||||||||||||||
| Capital expenditures | — | ||||||||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Intersegment revenues | ( | — | |||||||||||||||||||||||||||
| Revenue | ( | ||||||||||||||||||||||||||||
Purchased power(a) | ( | ( | |||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | — | ( | ||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other income, net | — | ||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Income (taxes) benefit | ( | ( | — | ( | |||||||||||||||||||||||||
| Net income (loss) available to common shareholder | ( | — | |||||||||||||||||||||||||||
| Interest income | — | ||||||||||||||||||||||||||||
| Capital expenditures | — | ||||||||||||||||||||||||||||
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| Reportable Segments | |||||||||||||||||||||||||||||
| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Intersegment Eliminations | Ameren Illinois | |||||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Intersegment revenues | ( | — | |||||||||||||||||||||||||||
| Revenue | ( | ||||||||||||||||||||||||||||
Purchased power(a) | ( | ( | |||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | — | ( | ||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other income, net | — | ||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | — | ( | ||||||||||||||||||||||||||
| Net income available to common shareholder | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Capital expenditures | — | ||||||||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||
| External revenues | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Intersegment revenues | ( | — | |||||||||||||||||||||||||||
| Revenue | ( | ||||||||||||||||||||||||||||
Purchased power(a) | ( | ( | |||||||||||||||||||||||||||
Natural gas purchased for resale(a) | ( | — | ( | ||||||||||||||||||||||||||
Other operations and maintenance expenses(a) | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other segment items | |||||||||||||||||||||||||||||
| Depreciation and amortization | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Taxes other than income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Other income, net | — | ||||||||||||||||||||||||||||
| Interest charges | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Income taxes | ( | ( | ( | — | ( | ||||||||||||||||||||||||
| Noncontrolling interests – preferred stock dividends | ( | — | ( | ||||||||||||||||||||||||||
| Net income available to common shareholder | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Interest income | $ | $ | $ | $ | — | $ | |||||||||||||||||||||||
| Capital expenditures | — | ||||||||||||||||||||||||||||
(a)Significant segment expense that is regularly provided to the CODMs. Intersegment expenses are included within the amounts shown.
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The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and nine months ended September 30, 2026 and 2025. 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 2026: | |||||||||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||||||||
| Total electric revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | |||||||||||||||||||||||||||||||||||
| Total natural gas revenues | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||||||||
| Total electric revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||||||||||||||
| Total natural gas revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | (a) | ( | |||||||||||||||||||||||||||||||||
| Total electric revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||||||||||||||
| Total natural gas revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
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| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Intersegment Eliminations | Ameren | ||||||||||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||||||||
| Total electric revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||||||||||||||
| Total natural gas revenues | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
(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, 2026 and 2025:
| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Intersegment Eliminations | Ameren | |||||||||||||||||||||||||||||||||
| Three Months 2026: | ||||||||||||||||||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | ( | $ | ( | $ | — | $ | ( | ||||||||||||||||||||||||||
| Other revenues not from contracts with customers | ( | |||||||||||||||||||||||||||||||||||||
| Three Months 2025: | ||||||||||||||||||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | $ | ( | $ | ( | $ | ( | $ | — | $ | ( | |||||||||||||||||||||||||||
| Other revenues not from contracts with customers | ||||||||||||||||||||||||||||||||||||||
| Nine Months 2026: | ||||||||||||||||||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | $ | ( | $ | — | $ | ( | |||||||||||||||||||||||||||
| Other revenues not from contracts with customers | ( | |||||||||||||||||||||||||||||||||||||
| Nine Months 2025: | ||||||||||||||||||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | ( | $ | ( | $ | — | $ | ( | ||||||||||||||||||||||||||
| Other revenues not from contracts with customers | ( | |||||||||||||||||||||||||||||||||||||
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Ameren Illinois
| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Intersegment Eliminations | Ameren Illinois | |||||||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||
| Other | (a) | ( | |||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||
| Residential | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Commercial | |||||||||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||||||||
| Other | ( | (a) | ( | ||||||||||||||||||||||||||
Total revenues(b) | $ | $ | $ | $ | ( | $ | |||||||||||||||||||||||
(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, 2026 and 2025:
| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Ameren Illinois | ||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other revenues not from contracts with customers | |||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other revenues not from contracts with customers | |||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | $ | ( | $ | ( | ||||||||||||||||
| Other revenues not from contracts with customers | |||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||
| Revenues from alternative revenue programs | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other revenues not from contracts with customers | |||||||||||||||||||||||
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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 in the MISO.
Ameren’s and Ameren Missouri’s financial statements are prepared on a consolidated basis and therefore include the accounts of their majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren 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 diluted share.
OVERVIEW
Net income attributable to Ameren common shareholders in the three months ended September 30, 2026, was $676 million, or $2.42 per diluted share, compared with $640 million, or $2.35 per diluted share, in the year-ago period. Net income attributable to Ameren common shareholders in the nine months ended September 30, 2026, was $1,347 million, or $4.83 per diluted share, compared with $1,204 million, or $4.43 per diluted share, in the year-ago period. Net income was favorably affected for the three and nine months ended September 30, 2026, by increased infrastructure investments across all segments, including infrastructure reflected in electric and natural gas service rates at Ameren Missouri, effective June 1, 2025 and September 1, 2025, respectively, and natural gas rates at Ameren Illinois, effective December 2, 2025. Net income for the three and nine months ended September 30, 2026, was also favorably affected by an increase in earnings from our equity method investments, primarily related to advancing innovative energy technologies, and favorable retail electric sales volumes at Ameren Missouri, excluding customer energy-efficiency programs, primarily due to growth in weather-normalized commercial and residential sales. Additionally, net income for the three months ended September 30, 2026, was favorably affected by increased retail electric sales at Ameren Missouri due to warmer weather. Net income was unfavorably affected for the three and nine months ended September 30, 2026, by increased other operations and maintenance expenses at Ameren Missouri not subject to riders or trackers, largely due to increased reliability measures at the Labadie and Sioux energy centers, increased vegetation management expenses, higher injuries and damage claims, and higher Callaway Energy Center refueling and maintenance outage cost amortization, and increased tax expense at Ameren Transmission due to the revaluation of excess deferred income tax regulatory liabilities in 2025. Earnings in the three and nine months ended September 30, 2026, were also unfavorably affected by higher weighted-average basic common shares outstanding in 2026 and increased financing costs.
Ameren’s strategic plan includes investing in rate-regulated energy infrastructure, enhancing regulatory frameworks and energy policies, and optimizing performance to deliver safe, reliable, and affordable energy for our customers and communities. Ameren remains focused on disciplined cost management and strategic capital allocation. Ameren invested $4.1 billion in its rate-regulated businesses in the nine months ended September 30, 2026.
In June 2026, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $343 million. The electric rate request is based on a 10.25% return on common equity, a capital structure composed of 52% common equity, a rate base of $16.7 billion, and a test year ended March 31, 2026, with certain pro-forma adjustments expected through an anticipated true-up date of December 31, 2026. 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 2027 and new rates effective by June 2027.
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In February 2026, the MoPSC issued an order approving a nonunanimous stipulation and agreement related to a requested CCN for the Big Hollow Natural Gas (800-MW facility) and the Big Hollow Battery Energy Storage (400-MW facility) projects. Also in February 2026, Ameren Missouri acquired the Split Rail Solar Project for approximately $0.6 billion and placed it in-service in June 2026. In May 2026, the MoPSC issued an order approving a nonunanimous stipulation and agreement related to a requested CCN for the Reform Solar Project (250-MW facility). In July 2026, Ameren Missouri filed for a CCN to construct the West Alton Natural Gas Project (2,100-MW facility). In October 2026, the MoPSC issued an order approving a nonunanimous stipulation and agreement related to requested CCNs for the Millcreek (250-MW facility), Huck Finn (200-MW facility), and Castle Bluff (95-MW facility) battery energy storage projects and the Ringer (225-MW facility) and Tom Sawyer (175-MW facility) solar projects.
In 2026, Ameren Missouri executed electric service agreements with large load customers under its modified large primary service tariff that was approved in 2025, representing 2.8 gigawatts of demand that is expected to begin materializing in the second half of 2027 and to reach full capacity in 2030. Ameren and Ameren Missouri do not expect a material impact to their results of operations, financial position, or liquidity in 2026 related to these agreements.
In September 2026, Ameren Missouri filed its preferred resource plan with the MoPSC. The plan outlines how Ameren Missouri expects to address load growth opportunities resulting from the electric service agreements discussed above and interest from other entities that are considering either locating or expanding their operations within Ameren Missouri’s service territory. The plan includes significant investment through 2045 in simple- and combined-cycle natural gas, solar, wind, and nuclear generation, as well as battery energy storage and natural gas fuel cells. It also includes retiring all of Ameren Missouri’s coal-fired energy centers by 2042 and certain natural gas-fired energy centers by 2040 to comply with Illinois law. In addition, Ameren Missouri expects to seek and receive NRC approval for an extension of the operating license for the Callaway Energy Center beyond its current 2044 expiration date.
In December 2024, the ICC issued an order in connection with a revised Grid Plan and a revised MYRP filed by Ameren Illinois in March 2024, approving revenue requirements for electric distribution services for 2024 through 2027 of $1,206 million, $1,287 million, $1,367 million, and $1,421 million, respectively. In May 2026, the Illinois Appellate Court for the Fifth Judicial District upheld the ICC’s December 2024 order and orders issued by the ICC in June 2024 and December 2023 following appeals by Ameren Illinois.
In December 2025, the ICC issued an order approving Ameren Illinois’ 2024 electric distribution service revenue requirement reconciliation adjustment filing. In March 2026, Ameren Illinois filed an appeal of the December 2025 order with the Illinois Appellate Court for the Fifth Judicial District and withdrew the appeal in July 2026 as a result of the appellate court decision in the MYRP proceeding discussed above.
In April 2026, Ameren Illinois filed a reconciliation adjustment to its 2025 electric distribution service revenue requirement with the ICC. In August 2026, Ameren Illinois updated its reconciliation adjustment, requesting recovery of $28 million. The adjustment reflects Ameren Illinois’ actual 2025 recoverable costs, 2025 year-end rate base, and a capital structure composed of 50% common equity. The ICC staff has not objected to Ameren Illinois’ updated reconciliation adjustment. In November 2026, the administrative law judges issued a proposed order consistent with Ameren Illinois’ request. An ICC decision is required by December 2026, and any approved adjustment would be collected from customers in 2027.
In May 2026, Ameren Illinois filed an electric energy efficiency plan with the ICC, which includes annual investments in electric energy-efficiency programs up to $192 million, $239 million, and $276 million for 2027, 2028, and 2029, respectively. 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 Ameren Illinois’ investments in electric energy-efficiency programs. A decision by the ICC in this proceeding is expected in November 2026.
In November 2025, the ICC issued an order in Ameren Illinois’ January 2025 natural gas delivery service regulatory rate review, which resulted in an increase to Ameren Illinois’ annual revenues for natural gas delivery service of $79 million based on a 9.60% ROE, a capital structure composed of 50% common equity, a 2026 future test year, and a rate base of $3.2 billion. The order reflected a reduction of $75 million of planned distribution and transmission capital investments included in Ameren Illinois’ future test year request. The new rates became effective in December 2025. In January 2026, Ameren Illinois filed an appeal of the ICC’s November 2025 order to the Illinois Appellate Court for the Fifth Judicial District. The appeal challenged the inclusion of the non-service cost component of the net periodic benefit income related to other postretirement benefits in the annual revenue requirement and the $75 million reduction of planned capital investments, among other things. The court is under no deadline to address the appeal.
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.
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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, the fair value of equity method investments, 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.
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 and interest rate risk as well as 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, 2026 and 2025:
| Three Months | Nine Months | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Net income attributable to Ameren common shareholders | $ | 676 | $ | 640 | $ | 1,347 | $ | 1,204 | |||||||||||||||
| Earnings per common share – diluted | 2.42 | 2.35 | 4.83 | 4.43 | |||||||||||||||||||
Net income attributable to Ameren common shareholders increased $36 million and earnings per diluted share increased 7 cents in the three months ended September 30, 2026, compared with the year-ago period. The increase was due to net income increases of $64 million and $15 million at Ameren Missouri and Ameren Illinois Electric Distribution, respectively, and a decrease in net loss of $6 million at Ameren Illinois Natural Gas. The above increases were partially offset by a $41 million reduction in net income at Ameren Transmission. Net income was further impacted by an increase in net loss of $8 million for activity not reported as part of a segment, primarily at Ameren (parent).
Net income attributable to Ameren common shareholders increased $143 million and earnings per diluted share increased 40 cents in the nine months ended September 30, 2026, compared with the year-ago period. The increase was due to net income increases of $105 million, $24 million, and $19 million at Ameren Missouri, Ameren Illinois Electric Distribution, and Ameren Illinois Natural Gas, respectively. The above increases were partially offset by a $22 million reduction in net income at Ameren Transmission. Net income was further impacted by a decrease in net loss of $17 million for activity not reported as part of a segment, primarily at Ameren (parent).
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Earnings per diluted share were favorably affected in the three and nine months ended September 30, 2026, compared to the year-ago periods (except where a specific period is referenced), by:
•a higher allowance for equity funds used during construction and increased base rate revenues at Ameren Missouri for the inclusion of previously deferred interest charges under PISA pursuant to the April 2025 MoPSC electric rate order, partially offset by lower interest deferrals associated with the PISA (9 cents and 24 cents per share, respectively);
•an increase in earnings from our equity method investments, primarily related to advancing innovative energy technologies in 2026 compared with a net loss on those investments in 2025 (9 cents and 18 cents per share, respectively);
•equity return on increased rate base investments at Ameren Transmission and Ameren Illinois Electric Distribution (6 cents and 16 cents per share, respectively);
•increased base rate revenues at Ameren Missouri, pursuant to the April 2025 MoPSC electric rate order, effective June 1, 2025, partially offset by higher depreciation and amortization and interest expenses in base rates (12 cents per share in the nine months ended September 30, 2026);
•increased base rate revenues at Ameren Illinois Natural Gas, pursuant to the November 2025 ICC natural gas rate order, effective December 2, 2025, partially offset by increased operations and maintenance, depreciation and amortization, and interest expenses included in base rates (3 cents and 9 cents per share, respectively);
•increased retail electric sales volumes at Ameren Missouri, excluding customer energy-efficiency programs, primarily due to warmer summer temperatures in the three month period ended September 30, 2026, and growth in weather-normalized commercial and residential sales volumes in the nine month period ended September 30, 2026 (estimated at 15 cents and 9 cents per share, respectively);
•increased base rate revenues at Ameren Missouri’s natural gas business, pursuant to the July 2025 MoPSC natural gas rate order, effective September 1, 2025, partially offset by higher depreciation and amortization expenses included in base rates (1 cent and 5 cents per share, respectively); and
•higher revenue at Ameren Missouri resulting from the absence in 2026 of a deferral associated with the Rush Island Energy Center (4 cents per share in the nine months ended September 30, 2026).
Earnings per diluted share were unfavorably affected in the three and nine months ended September 30, 2026, compared to the year-ago periods by:
•increased other operations and maintenance expenses at Ameren Missouri not subject to riders or trackers, largely due to increased reliability measures at the Labadie and Sioux energy centers, increased vegetation management expenses, higher injuries and damage claims, and higher Callaway Energy Center refueling and maintenance outage cost amortization (10 cents and 24 cents per share, respectively);
•the absence in 2026 of a decrease in income tax expense at Ameren Transmission resulting from the revaluation of excess deferred income tax regulatory liabilities, resulting from TCJA for FERC-regulated jurisdictions, related to ratemaking treatment of net operating loss carryforwards by affiliates under a tax allocation agreement, see Note 12 – Income Taxes under Part I, Item 1, of this report for additional information (18 cents per share for both periods);
•increased weighted-average basic common shares outstanding resulting from issuances of common shares (6 cents and 12 cents per share, respectively); and
•increased financing costs, primarily at Ameren Missouri and Ameren (parent), largely due to higher rates on higher long-term debt balances (5 cents and 9 cents per share, respectively).
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, 2025, 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 2026 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, 2026 and 2025:
| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Other / Intersegment Eliminations | Ameren | ||||||||||||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||||||||||||||
| Electric revenues | $ | 1,757 | $ | 777 | $ | — | $ | 266 | $ | (78) | $ | 2,722 | |||||||||||||||||||||||
| Natural gas revenues | 24 | — | 136 | — | — | 160 | |||||||||||||||||||||||||||||
| Fuel and purchased power | (509) | (360) | — | — | 60 | (809) | |||||||||||||||||||||||||||||
| Natural gas purchased for resale | (5) | — | (23) | — | — | (28) | |||||||||||||||||||||||||||||
| Other operations and maintenance expenses | (274) | (182) | (58) | (34) | 13 | (535) | |||||||||||||||||||||||||||||
| Depreciation and amortization expenses | (246) | (100) | (34) | (55) | (1) | (436) | |||||||||||||||||||||||||||||
| Taxes other than income taxes | (129) | (23) | (17) | (2) | (3) | (174) | |||||||||||||||||||||||||||||
| Operating income (loss) | 618 | 112 | 4 | 175 | (9) | 900 | |||||||||||||||||||||||||||||
| Other income, net | 58 | 17 | 3 | 6 | 28 | 112 | |||||||||||||||||||||||||||||
| Interest charges | (82) | (30) | (18) | (32) | (54) | (216) | |||||||||||||||||||||||||||||
| Income (taxes) benefit | (11) | (27) | 4 | (39) | (46) | (119) | |||||||||||||||||||||||||||||
| Net income (loss) | 583 | 72 | (7) | 110 | (81) | 677 | |||||||||||||||||||||||||||||
Noncontrolling interests – preferred stock dividends | (1) | — | — | — | — | (1) | |||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | 582 | $ | 72 | $ | (7) | $ | 110 | $ | (81) | $ | 676 | |||||||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||||||||
| Electric revenues | $ | 1,685 | $ | 699 | $ | — | $ | 240 | $ | (61) | $ | 2,563 | |||||||||||||||||||||||
| Natural gas revenues | 20 | — | 117 | — | (1) | 136 | |||||||||||||||||||||||||||||
| Fuel and purchased power | (487) | (330) | — | — | 49 | (768) | |||||||||||||||||||||||||||||
| Natural gas purchased for resale | (6) | — | (19) | — | — | (25) | |||||||||||||||||||||||||||||
| Other operations and maintenance expenses | (260) | (171) | (55) | (19) | 3 | (502) | |||||||||||||||||||||||||||||
| Depreciation and amortization expenses | (239) | (92) | (33) | (49) | (2) | (415) | |||||||||||||||||||||||||||||
| Taxes other than income taxes | (122) | (22) | (15) | (3) | (2) | (164) | |||||||||||||||||||||||||||||
| Operating income (loss) | 591 | 84 | (5) | 169 | (14) | 825 | |||||||||||||||||||||||||||||
| Other income (expense), net | 45 | 20 | 4 | (3) | 10 | 76 | |||||||||||||||||||||||||||||
| Interest charges | (85) | (28) | (16) | (31) | (48) | (208) | |||||||||||||||||||||||||||||
| Income (taxes) benefit | (32) | (19) | 4 | 16 | (21) | (52) | |||||||||||||||||||||||||||||
| Net income (loss) | 519 | 57 | (13) | 151 | (73) | 641 | |||||||||||||||||||||||||||||
Noncontrolling interests – preferred stock dividends | (1) | — | — | — | — | (1) | |||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | 518 | $ | 57 | $ | (13) | $ | 151 | $ | (73) | $ | 640 | |||||||||||||||||||||||
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| Ameren Missouri | Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Transmission | Other / Intersegment Eliminations | Ameren | ||||||||||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||||||||
| Electric revenues | $ | 3,702 | $ | 2,049 | $ | — | $ | 722 | $ | (203) | $ | 6,270 | |||||||||||||||||||||||
| Natural gas revenues | 133 | — | 748 | — | (1) | 880 | |||||||||||||||||||||||||||||
| Fuel and purchased power | (1,041) | (864) | — | — | 156 | (1,749) | |||||||||||||||||||||||||||||
| Natural gas purchased for resale | (46) | — | (192) | — | — | (238) | |||||||||||||||||||||||||||||
| Other operations and maintenance expenses | (820) | (507) | (182) | (74) | 36 | (1,547) | |||||||||||||||||||||||||||||
| Depreciation and amortization expenses | (694) | (294) | (101) | (160) | (5) | (1,254) | |||||||||||||||||||||||||||||
| Taxes other than income taxes | (325) | (66) | (63) | (7) | (10) | (471) | |||||||||||||||||||||||||||||
| Operating income (loss) | 909 | 318 | 210 | 481 | (27) | 1,891 | |||||||||||||||||||||||||||||
| Other income, net | 171 | 54 | 10 | 19 | 66 | 320 | |||||||||||||||||||||||||||||
| Interest charges | (247) | (86) | (51) | (94) | (151) | (629) | |||||||||||||||||||||||||||||
| Income (taxes) benefit | (15) | (77) | (45) | (102) | 8 | (231) | |||||||||||||||||||||||||||||
| Net income (loss) | 818 | 209 | 124 | 304 | (104) | 1,351 | |||||||||||||||||||||||||||||
Noncontrolling interests – preferred stock dividends | (3) | (1) | — | — | — | (4) | |||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | 815 | $ | 208 | $ | 124 | $ | 304 | $ | (104) | $ | 1,347 | |||||||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||||||||
| Electric revenues | $ | 3,893 | $ | 1,844 | $ | — | $ | 658 | $ | (172) | $ | 6,223 | |||||||||||||||||||||||
| Natural gas revenues | 109 | — | 686 | — | (1) | 794 | |||||||||||||||||||||||||||||
| Fuel and purchased power | (1,431) | (765) | — | — | 132 | (2,064) | |||||||||||||||||||||||||||||
| Natural gas purchased for resale | (45) | — | (188) | — | — | (233) | |||||||||||||||||||||||||||||
| Other operations and maintenance expenses | (748) | (493) | (165) | (56) | 15 | (1,447) | |||||||||||||||||||||||||||||
| Depreciation and amortization expenses | (642) | (276) | (98) | (146) | (6) | (1,168) | |||||||||||||||||||||||||||||
| Taxes other than income taxes | (300) | (63) | (60) | (7) | (9) | (439) | |||||||||||||||||||||||||||||
| Operating income (loss) | 836 | 247 | 175 | 449 | (41) | 1,666 | |||||||||||||||||||||||||||||
| Other income, net | 135 | 66 | 14 | 14 | 28 | 257 | |||||||||||||||||||||||||||||
| Interest charges | (215) | (80) | (47) | (89) | (139) | (570) | |||||||||||||||||||||||||||||
| Income (taxes) benefit | (43) | (48) | (37) | (48) | 31 | (145) | |||||||||||||||||||||||||||||
| Net income (loss) | 713 | 185 | 105 | 326 | (121) | 1,208 | |||||||||||||||||||||||||||||
Noncontrolling interests – preferred stock dividends | (3) | (1) | — | — | — | (4) | |||||||||||||||||||||||||||||
| Net income (loss) attributable to Ameren common shareholders | $ | 710 | $ | 184 | $ | 105 | $ | 326 | $ | (121) | $ | 1,204 | |||||||||||||||||||||||
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Below is Ameren Illinois’ table of income statement components by segment for the three and nine months ended September 30, 2026 and 2025:
| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Other / Intersegment Eliminations | Ameren Illinois | |||||||||||||||||||||||||
| Three Months 2026: | |||||||||||||||||||||||||||||
| Electric revenues | $ | 777 | $ | — | $ | 196 | $ | (56) | $ | 917 | |||||||||||||||||||
| Natural gas revenues | — | 136 | — | — | 136 | ||||||||||||||||||||||||
| Purchased power | (360) | — | — | 56 | (304) | ||||||||||||||||||||||||
| Natural gas purchased for resale | — | (23) | — | — | (23) | ||||||||||||||||||||||||
| Other operations and maintenance expenses | (182) | (58) | (25) | — | (265) | ||||||||||||||||||||||||
| Depreciation and amortization expenses | (100) | (34) | (41) | — | (175) | ||||||||||||||||||||||||
| Taxes other than income taxes | (23) | (17) | (2) | — | (42) | ||||||||||||||||||||||||
| Operating income | 112 | 4 | 128 | — | 244 | ||||||||||||||||||||||||
| Other income, net | 17 | 3 | 5 | — | 25 | ||||||||||||||||||||||||
| Interest charges | (30) | (18) | (24) | — | (72) | ||||||||||||||||||||||||
| Income (taxes) benefit | (27) | 4 | (30) | — | (53) | ||||||||||||||||||||||||
| Net income (loss) attributable to common shareholders | $ | 72 | $ | (7) | $ | 79 | $ | — | $ | 144 | |||||||||||||||||||
| Three Months 2025: | |||||||||||||||||||||||||||||
| Electric revenues | $ | 699 | $ | — | $ | 176 | $ | (46) | $ | 829 | |||||||||||||||||||
| Natural gas revenues | — | 117 | — | — | 117 | ||||||||||||||||||||||||
| Purchased power | (330) | — | — | 46 | (284) | ||||||||||||||||||||||||
| Natural gas purchased for resale | — | (19) | — | — | (19) | ||||||||||||||||||||||||
| Other operations and maintenance expenses | (171) | (55) | (15) | — | (241) | ||||||||||||||||||||||||
| Depreciation and amortization expenses | (92) | (33) | (37) | — | (162) | ||||||||||||||||||||||||
| Taxes other than income taxes | (22) | (15) | (1) | — | (38) | ||||||||||||||||||||||||
| Operating income (loss) | 84 | (5) | 123 | — | 202 | ||||||||||||||||||||||||
| Other income, net | 20 | 4 | 6 | — | 30 | ||||||||||||||||||||||||
| Interest charges | (28) | (16) | (23) | — | (67) | ||||||||||||||||||||||||
| Income (taxes) benefit | (19) | 4 | (2) | — | (17) | ||||||||||||||||||||||||
| Net income (loss) attributable to common shareholders | $ | 57 | $ | (13) | $ | 104 | $ | — | $ | 148 | |||||||||||||||||||
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| Ameren Illinois Electric Distribution | Ameren Illinois Natural Gas | Ameren Illinois Transmission | Other / Intersegment Eliminations | Ameren Illinois | |||||||||||||||||||||||||
| Nine Months 2026: | |||||||||||||||||||||||||||||
| Electric revenues | $ | 2,049 | $ | — | $ | 528 | $ | (145) | $ | 2,432 | |||||||||||||||||||
| Natural gas revenues | — | 748 | — | — | 748 | ||||||||||||||||||||||||
| Purchased power | (864) | — | — | 145 | (719) | ||||||||||||||||||||||||
| Natural gas purchased for resale | — | (192) | — | — | (192) | ||||||||||||||||||||||||
| Other operations and maintenance expenses | (507) | (182) | (56) | — | (745) | ||||||||||||||||||||||||
| Depreciation and amortization expenses | (294) | (101) | (122) | — | (517) | ||||||||||||||||||||||||
| Taxes other than income taxes | (66) | (63) | (4) | — | (133) | ||||||||||||||||||||||||
| Operating income | 318 | 210 | 346 | — | 874 | ||||||||||||||||||||||||
| Other income, net | 54 | 10 | 16 | — | 80 | ||||||||||||||||||||||||
| Interest charges | (86) | (51) | (72) | — | (209) | ||||||||||||||||||||||||
| Income taxes | (77) | (45) | (75) | — | (197) | ||||||||||||||||||||||||
| Net income | 209 | 124 | 215 | — | 548 | ||||||||||||||||||||||||
| Preferred stock dividends | (1) | — | — | — | (1) | ||||||||||||||||||||||||
| Net income attributable to common shareholder | $ | 208 | $ | 124 | $ | 215 | $ | — | $ | 547 | |||||||||||||||||||
| Nine Months 2025: | |||||||||||||||||||||||||||||
| Electric revenues | $ | 1,844 | $ | — | $ | 482 | $ | (123) | $ | 2,203 | |||||||||||||||||||
| Natural gas revenues | — | 686 | — | — | 686 | ||||||||||||||||||||||||
| Purchased power | (765) | — | — | 123 | (642) | ||||||||||||||||||||||||
| Natural gas purchased for resale | — | (188) | — | — | (188) | ||||||||||||||||||||||||
| Other operations and maintenance expenses | (493) | (165) | (44) | — | (702) | ||||||||||||||||||||||||
| Depreciation and amortization expenses | (276) | (98) | (110) | — | (484) | ||||||||||||||||||||||||
| Taxes other than income taxes | (63) | (60) | (3) | — | (126) | ||||||||||||||||||||||||
| Operating income | 247 | 175 | 325 | — | 747 | ||||||||||||||||||||||||
| Other income, net | 66 | 14 | 21 | — | 101 | ||||||||||||||||||||||||
| Interest charges | (80) | (47) | (65) | — | (192) | ||||||||||||||||||||||||
| Income taxes | (48) | (37) | (49) | — | (134) | ||||||||||||||||||||||||
| Net income | 185 | 105 | 232 | — | 522 | ||||||||||||||||||||||||
| Preferred stock dividends | (1) | — | — | — | (1) | ||||||||||||||||||||||||
| Net income attributable to common shareholder | $ | 184 | $ | 105 | $ | 232 | $ | — | $ | 521 | |||||||||||||||||||
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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, 2026, 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) | $ | — | $ | 23 | $ | — | $ | 26 | $ | — | $ | 49 | |||||||||||||||||||||||
Effect of weather (estimate)(c) | 39 | — | — | — | — | 39 | |||||||||||||||||||||||||||||
| Retail sales volumes and changes in customer usage patterns (normalized for the estimated effects of weather and MEEIA) | 17 | — | — | — | — | 17 | |||||||||||||||||||||||||||||
| Transmission service charges (not included in the FAC) | 2 | — | — | — | — | 2 | |||||||||||||||||||||||||||||
| Off-system sales, capacity, transmission, and FAC revenues, net | (37) | — | — | — | — | (37) | |||||||||||||||||||||||||||||
| Ameren Illinois energy-efficiency program investment revenues | — | 3 | — | — | — | 3 | |||||||||||||||||||||||||||||
Electric deferred income tax adjustment(d) | — | 10 | — | — | — | 10 | |||||||||||||||||||||||||||||
| Customer generation rebate program revenues | — | 8 | — | — | — | 8 | |||||||||||||||||||||||||||||
RESRAM(e) | (6) | — | — | — | — | (6) | |||||||||||||||||||||||||||||
| Other | 2 | 2 | — | — | (6) | (2) | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in fuel and purchased power(f) | 51 | 30 | — | — | (11) | 70 | |||||||||||||||||||||||||||||
Other cost recovery mechanisms(g) | 4 | 2 | — | — | — | 6 | |||||||||||||||||||||||||||||
| Total electric revenue change | $ | 72 | $ | 78 | $ | — | $ | 26 | $ | (17) | $ | 159 | |||||||||||||||||||||||
| Natural gas revenue change: | |||||||||||||||||||||||||||||||||||
| Base rates (estimate) | $ | 5 | $ | — | $ | 9 | $ | — | $ | — | $ | 14 | |||||||||||||||||||||||
| Change in rate design (estimate) | — | — | 4 | — | — | 4 | |||||||||||||||||||||||||||||
| Other | — | — | — | — | 1 | 1 | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in natural gas purchased for resale(f) | (1) | — | 4 | — | — | 3 | |||||||||||||||||||||||||||||
Other cost recovery mechanisms(g) | — | — | 2 | — | — | 2 | |||||||||||||||||||||||||||||
| Total natural gas revenue change | $ | 4 | $ | — | $ | 19 | $ | — | $ | 1 | $ | 24 | |||||||||||||||||||||||
| Nine Months | |||||||||||||||||||||||||||||||||||
| Electric revenue change: | |||||||||||||||||||||||||||||||||||
Base rates (estimate)(b) | $ | 118 | $ | 66 | $ | — | $ | 64 | $ | — | $ | 248 | |||||||||||||||||||||||
Effect of weather (estimate)(c) | 9 | — | — | — | — | 9 | |||||||||||||||||||||||||||||
| Retail sales volumes and changes in customer usage patterns (normalized for the estimated effects of weather and MEEIA) | 29 | — | — | — | — | 29 | |||||||||||||||||||||||||||||
| Transmission service charges (not included in the FAC) | 8 | — | — | — | — | 8 | |||||||||||||||||||||||||||||
| Off-system sales, capacity, and FAC revenues, net | (515) | — | — | — | — | (515) | |||||||||||||||||||||||||||||
| Ameren Illinois energy-efficiency program investment revenues | — | 8 | — | — | — | 8 | |||||||||||||||||||||||||||||
Electric deferred income tax adjustment(d) | — | 21 | — | — | — | 21 | |||||||||||||||||||||||||||||
| Rush Island Energy Center base rate revenue deferral | 26 | — | — | — | — | 26 | |||||||||||||||||||||||||||||
| Customer generation rebate program revenues | — | 15 | — | — | — | 15 | |||||||||||||||||||||||||||||
RESRAM(e) | 6 | — | — | — | — | 6 | |||||||||||||||||||||||||||||
| Other | 6 | 2 | — | — | (7) | 1 | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in fuel and purchased power(f) | 110 | 99 | — | — | (24) | 185 | |||||||||||||||||||||||||||||
Other cost recovery mechanisms(g) | 12 | (6) | — | — | — | 6 | |||||||||||||||||||||||||||||
| Total electric revenue change | $ | (191) | $ | 205 | $ | — | $ | 64 | $ | (31) | $ | 47 | |||||||||||||||||||||||
| Natural gas revenue change: | |||||||||||||||||||||||||||||||||||
| Base rates (estimate) | $ | 22 | $ | — | $ | 52 | $ | — | $ | — | $ | 74 | |||||||||||||||||||||||
| Change in rate design (estimate) | — | — | 3 | — | — | 3 | |||||||||||||||||||||||||||||
Effect of weather (estimate)(c) | (3) | — | — | — | — | (3) | |||||||||||||||||||||||||||||
| Other | 1 | — | (1) | — | — | — | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in natural gas purchased for resale(f) | 4 | — | 4 | — | — | 8 | |||||||||||||||||||||||||||||
Other cost recovery mechanisms(g) | — | — | 4 | — | — | 4 | |||||||||||||||||||||||||||||
| Total natural gas revenue change | $ | 24 | $ | — | $ | 62 | $ | — | $ | — | $ | 86 | |||||||||||||||||||||||
(a)Includes an increase in transmission revenues of $20 million and $46 million at Ameren Illinois for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods.
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(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 “Retail sales volumes and changes in customer usage patterns (normalized for 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 certain excess deferred income taxes that were 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)Changes in RESRAM revenues are largely offset in “Fuel and purchased power,” “Other operations and maintenance,” “Depreciation and amortization,” “Taxes other than income taxes,” or “Income taxes” on the statement of income.
(f)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, 2026, activity in Other/Intersegment Eliminations of $11 million and $24 million, respectively, was primarily due to the changes in Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution (-$10 million and -$22 million, respectively). See 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.
(g)Offsetting expense increases or decreases are reflected in “Other operations and maintenance,” “Taxes other than income taxes,” or “Income taxes” on the statement of income. These items have no overall impact on earnings.
Electric Revenues
Ameren
Ameren’s electric revenues increased $159 million, or 6%, for the three months ended September 30, 2026, compared with the year-ago period, due to increased revenues at Ameren Illinois Electric Distribution, Ameren Missouri, and Ameren Transmission. For the nine months ended September 30, 2026, Ameren’s electric revenues increased $47 million, or 1%, compared with the year-ago period, primarily due to increased revenues at Ameren Illinois Electric Distribution and Ameren Transmission, partially offset by decreased revenues at Ameren Missouri.
Ameren Transmission
Ameren Transmission’s electric revenues increased $26 million, or 11%, and $64 million, or 10%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. Revenues were affected by higher recoverable expenses (+$17 million and +$39 million, respectively) and return on higher rate base (+$9 million and +$25 million, respectively), as evidenced by a 9% increase in rate base used to calculate the revenue requirement.
Ameren Missouri
Ameren Missouri’s electric revenues increased $72 million, or 4%, and decreased $191 million, or 5%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods.
“Off-system sales, capacity, transmission, and FAC revenues, net” decreased $37 million and $515 million, respectively, for the three and nine months ended September 30, 2026, primarily due to spring and summer capacity prices decreasing from $720 and $667 per MW-day in 2025 to $70 and $424 per MW-day, respectively, in 2026 as a result of the annual MISO auctions. The decrease in “Off-system sales, capacity, transmission, and FAC revenues, net” is largely offset by a decrease in fuel and purchased power expenses under “Energy costs”.
The following items increased Ameren Missouri’s electric revenues for the three and nine months ended September 30, 2026 (except where a specific period is referenced):
•Higher electric base rates, excluding the change in base rates for the MEEIA customer energy-efficiency programs and the RESRAM, resulting from the April 2025 MoPSC electric rate order effective June 1, 2025, increased revenues an estimated $118 million for the nine months ended September 30, 2026.
•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” increased $51 million and $110 million, respectively, due to increased revenue related to the recovery of costs previously deferred under the FAC. 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.
•Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues increased an estimated $17 million and $29 million, respectively, primarily due to increased weather-normalized commercial and residential retail sales volumes.
•For the nine months ended September 30, 2026, revenues increased $26 million due to the absence of the deferral of base rate revenues to a regulatory liability related to the Rush Island Energy Center following its October 15, 2024 retirement date, in accordance with the June 2024 MoPSC financing order. The deferral ended with new rates effective June 1, 2025.
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•The effect of weather increased revenues an estimated $39 million and $9 million, respectively, due to warmer summer temperatures, partially offset by milder winter and spring temperatures.
Ameren Illinois
Ameren Illinois’ electric revenues increased $88 million, or 11%, and $229 million, or 10%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, driven by increased revenues at Ameren Illinois Electric Distribution and Ameren Illinois Transmission.
Ameren Illinois Electric Distribution
Ameren Illinois Electric Distribution’s revenues increased $78 million, or 11%, and $205 million, or 11%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods.
The following items increased Ameren Illinois Electric Distribution’s revenues for the three and nine months ended September 30, 2026:
•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” increased $30 million and $99 million, respectively, due to increased purchased power expenses recovered from customers. The increase in electric revenues is fully offset by an increase in purchased power expenses under cost recovery mechanisms for purchased power, as discussed below.
•Base rates increased revenues by $23 million and $66 million, respectively, due to higher recoverable non-purchased power expenses (+$18 million and +$55 million, respectively) and return on higher rate base (+$5 million and +$11 million, respectively).
•Revenues increased $10 million and $21 million, respectively, due to the absence of amortization of certain excess deferred income taxes in 2025.
•Revenues increased $8 million and $15 million, respectively, due to the recovery of (+$5 million and +$10 million, respectively) and return on (+$3 million and +$5 million, respectively) increased customer generation rebates under performance-based formula ratemaking.
•Revenues increased $3 million and $8 million, respectively, due to the recovery of (+$2 million and +$6 million, respectively) and return on (+$1 million and +$2 million, respectively) increased energy-efficiency program investments under performance-based formula ratemaking.
Other cost recovery mechanisms decreased revenues $6 million for the nine months ended September 30, 2026, primarily due to a lower amount of customer bad debt costs included in customer rates pursuant to the associated rider.
Ameren Illinois Transmission
Ameren Illinois Transmission’s revenues increased $20 million, or 11%, and $46 million, or 10%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. Base rate revenues were primarily affected by higher recoverable expenses (+$14 million and +$31 million, respectively) and return on higher rate base (+$6 million and +$15 million, respectively), as evidenced by an 8% increase in rate base used to calculate the revenue requirement.
Ameren
Ameren’s natural gas revenues increased $24 million, or 18%, and $86 million, or 11%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, due to increased revenues at Ameren Illinois Natural Gas and Ameren Missouri, as discussed below.
Ameren Missouri
Ameren Missouri’s natural gas revenues were comparable for the three months ended September 30, 2026, and increased $24 million, or 22%, for the nine months ended September 30, 2026, compared with the year-ago period, primarily due to the effect of higher natural gas base rates as a result of the July 2025 MoPSC natural gas rate order effective September 1, 2025.
Ameren Illinois Natural Gas
Ameren Illinois Natural Gas’ revenues increased $19 million, or 16%, and $62 million, or 9%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. Base rate revenue increased an estimated $9 million and $52 million, respectively, for the three and nine months ended September 30, 2026, due to higher natural gas rates as a result of the November 2025 natural gas rate order, effective December 2, 2025. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information regarding the November 2025 natural gas rate order.
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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, 2026, 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) | $ | (36) | $ | — | $ | — | $ | — | $ | — | $ | (36) | |||||||||||||||||||||||
| Retail sales volume (excluding the estimated effect of weather) | 1 | — | — | — | — | 1 | |||||||||||||||||||||||||||||
Effect of weather (estimate)(a) | 4 | — | — | — | — | 4 | |||||||||||||||||||||||||||||
| Transmission service charges (not included in the FAC) | 2 | — | — | — | — | 2 | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in electric revenue(b) | 51 | 30 | — | — | (11) | 70 | |||||||||||||||||||||||||||||
| Total fuel and purchased power change | $ | 22 | $ | 30 | $ | — | $ | — | $ | (11) | $ | 41 | |||||||||||||||||||||||
| Nine Months | |||||||||||||||||||||||||||||||||||
| Fuel and purchased power change: | |||||||||||||||||||||||||||||||||||
| Energy costs (excluding the estimated effect of weather) | $ | (514) | $ | — | $ | — | $ | — | $ | — | $ | (514) | |||||||||||||||||||||||
| Retail sales volume (excluding the estimated effect of weather) | 4 | — | — | — | — | 4 | |||||||||||||||||||||||||||||
Effect of weather (estimate)(a) | (1) | — | — | — | — | (1) | |||||||||||||||||||||||||||||
| Transmission service charges (not included in the FAC) | 7 | — | — | — | — | 7 | |||||||||||||||||||||||||||||
| Effect of higher net energy costs included in base rates | 5 | — | — | — | — | 5 | |||||||||||||||||||||||||||||
| Other | (1) | — | — | — | — | (1) | |||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in electric revenue(b) | 110 | 99 | — | — | (24) | 185 | |||||||||||||||||||||||||||||
| Total fuel and purchased power change | $ | (390) | $ | 99 | $ | — | $ | — | $ | (24) | $ | (315) | |||||||||||||||||||||||
(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, 2026, activity in Other/Intersegment Eliminations of $11 million and $24 million, respectively, was primarily due to the changes in Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution (-$10 million and -$22 million, respectively). See 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.
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 $41 million, or 5%, for the three months ended September 30, 2026, and decreased $315 million, or 15%, for the nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to decreased fuel and purchased power expenses at Ameren Missouri, partially offset by increased fuel and purchased power expenses at Ameren Illinois Electric Distribution, as discussed below.
Ameren Missouri
Ameren Missouri’s fuel and purchased power expenses increased $22 million, or 5%, for the three months ended September 30, 2026, and decreased $390 million, or 27%, for the nine months ended September 30, 2026, compared with the year-ago periods. Energy costs decreased $36 million and $514 million, respectively, primarily due to spring and summer capacity prices decreasing from $720 and $667 per MW-day in 2025 to $70 and $424 per MW-day, respectively, in 2026 as a result of the annual MISO auctions. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC increased $1 million in the three and nine months ended September 30, 2026, represented by the difference between “Off-system sales, capacity, transmission, and FAC revenues, net” in electric revenues and “Energy costs (excluding the estimated effect of weather)”. “Cost recovery mechanisms — offset in electric revenue” increased fuel and purchased power expenses $51 million and $110 million, respectively, due to increased recovery 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.
Ameren Illinois Electric Distribution
Ameren Illinois Electric Distribution’s purchased power expenses increased $30 million, or 9%, and $99 million, or 13%, for the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. This is primarily due to increased energy prices, transmission service charges and volumes. 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, 2026, 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: | |||||||||||||||||||||||||||||||||||
Cost recovery mechanisms – offset in natural gas revenue(b) | (1) | — | 4 | — | — | 3 | |||||||||||||||||||||||||||||
| Total natural gas purchased for resale change | $ | (1) | $ | — | $ | 4 | $ | — | $ | — | $ | 3 | |||||||||||||||||||||||
| Nine Months | |||||||||||||||||||||||||||||||||||
| Natural gas purchased for resale change: | |||||||||||||||||||||||||||||||||||
Effect of weather (estimate)(a) | $ | (3) | $ | — | $ | — | $ | — | $ | — | $ | (3) | |||||||||||||||||||||||
Cost recovery mechanisms – offset in natural gas revenue(b) | 4 | — | 4 | — | — | 8 | |||||||||||||||||||||||||||||
| Total natural gas purchased for resale change | $ | 1 | $ | — | $ | 4 | $ | — | $ | — | $ | 5 | |||||||||||||||||||||||
(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 Missouri and Ameren Illinois are allowed to pass on to customers prudently incurred costs for natural gas purchased for resale. Natural gas purchased for resale expenses were comparable between periods at Ameren, Ameren Missouri, and Ameren Illinois Natural Gas.
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Other Operations and Maintenance Expenses
| Increase (Decrease) by Segment | ||||||||||||||||||||
Overall Ameren Increase of $33 Million (QTD YoY) | Overall Ameren Increase of $100 Million (YTD YoY) | |||||||||||||||||||
Total by Segment(a) | ||||||||||||||||||||
(a)Includes $34 million and $19 million at Ameren Transmission in the three months ended September 30, 2026 and 2025, respectively. Includes other/intersegment eliminations of $(13) million and $(3) million in the three months ended September 30, 2026 and 2025, respectively. Also includes other/intersegment eliminations of $(36) million and $(15) million in the nine months ended September 30, 2026 and 2025, respectively.
| Ameren Missouri | Ameren Illinois Natural Gas | Other/Intersegment Eliminations | |||||||||||||||||||||||||||
| Ameren Illinois Electric Distribution | Ameren Transmission | ||||||||||||||||||||||||||||
Ameren
Other operations and maintenance expenses increased $33 million and $100 million in the three and nine months ended September 30, 2026, respectively, due to the changes discussed below. In addition to changes by segments discussed below, other operations and maintenance expenses decreased $10 million and $21 million, respectively, for activity not reported as part of a segment, as reflected in “Other/Intersegment Eliminations” above. This is primarily due to a decrease of $5 million and $15 million, respectively, in the elimination of the non-service cost component of net periodic benefit income. 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 $15 million and $18 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to a $10 million increase in software costs.
Ameren Missouri
Other operations and maintenance expenses increased $14 million and $72 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to the following items (except where a specific period is referenced):
•Non-nuclear generation operations and maintenance expenses increased $5 million and $25 million, respectively, primarily due to increased reliability measures at the Labadie and Sioux energy centers.
•Transmission and distribution expenditures, excluding major storm-related expenses, increased $6 million and $20 million, respectively, largely due to increased vegetation management expenditures.
•Callaway Energy Center operating costs increased $11 million in the nine months ended September 30, 2026, primarily due to increased amortization costs from the spring 2025 refueling and maintenance outage.
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•Injuries and damages increased $9 million in the nine months ended September 30, 2026, due to higher claim expenses.
The increase in other operations and maintenance expenses was partially offset for the nine months ended September 30, 2026, compared with the year-ago period, by a $6 million decrease in major storm-related expenses.
Ameren Illinois
Other operations and maintenance expenses increased $24 million and $43 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to the following items:
Ameren Illinois Electric Distribution
Other operations and maintenance expenses increased $11 million and $14 million in the three and nine months ended September 30, 2026, respectively, primarily due to the following items (except where a specific period is referenced):
•Increased costs associated with customer generation rebates and energy-efficiency program investments under formula ratemaking of $4 million and $10 million, respectively, due to increased amortization of regulatory assets.
•Increased costs of $9 million resulting from expanding programs under CEJA in the nine months ended September 30, 2026.
•Distribution expenditures increased $2 million and $5 million, respectively, largely due to increased vegetation management expenditures.
•Storm-related expenses, including related amortizations of previously deferred amounts, increased $3 million in the three months ended September 30, 2026, due to major storms experienced throughout its service territory in 2026.
The increase in other operations and maintenance expenses was partially offset for the nine months ended September 30, 2026, compared with the year-ago period, due to a $9 million decrease in bad debt expense, primarily due to a reduction in the base level of expense reflected in customer rates under the associated rider, effective June 2025.
Ameren Illinois Natural Gas
Other operations and maintenance expenses were comparable in the three months ended September 30, 2026 and increased $17 million in the nine months ended September 30, 2026, primarily due to increased natural gas storage costs of $8 million and increased customer bad debts of $3 million.
Ameren Illinois Transmission
Other operations and maintenance expenses increased $10 million and $12 million in the three and nine months ended September 30, 2026, respectively, primarily due to an increase of $10 million related to software costs.
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Depreciation and Amortization Expenses
| Increase (Decrease) by Segment | ||||||||||||||||||||
Overall Ameren Increase of $21 Million (QTD YoY) | Overall Ameren Increase of $86 Million (YTD YoY) | |||||||||||||||||||
Total by Segment(a) | ||||||||||||||||||||
(a)Includes other/intersegment eliminations of $1 million and $2 million in the three months ended September 30, 2026 and 2025, respectively. Also includes other/intersegment eliminations of $5 million and $6 million in the nine months ended September 30, 2026 and 2025, respectively.
| Ameren Missouri | Ameren Illinois Natural Gas | Other/Intersegment Eliminations | |||||||||||||||||||||||||||
| Ameren Illinois Electric Distribution | Ameren Transmission | ||||||||||||||||||||||||||||
Depreciation and amortization expenses increased $21 million, $13 million, and $7 million in the three months ended September 30, 2026, compared with the year-ago period at Ameren, Ameren Illinois, and Ameren Missouri, respectively, primarily because of additional property, plant, and equipment investments. Depreciation and amortization expenses increased $86 million, $52 million, and $33 million in the nine months ended September 30, 2026 at Ameren, Ameren Missouri, and Ameren Illinois, respectively, primarily because of additional property, plant, and equipment investments. Ameren’s and Ameren Missouri’s depreciation and amortization expenses for the nine months ended September 30, 2026, compared with the year-ago period, were affected by the following:
•Increased depreciation and amortization of $25 million due to the inclusion in base rates of property, plant, and equipment previously eligible for deferral to a regulatory asset under the PISA and RESRAM effective June 1, 2025, pursuant to the April 2025 MoPSC electric rate order.
•Lower net deferrals and increased amortization of prior deferrals under PISA, which increased depreciation and amortization expenses by $7 million.
•Depreciation and amortization rate changes effective June 1, 2025, pursuant to the April 2025 MoPSC electric rate order, which increased depreciation and amortization expenses by $6 million.
•The lower net under-recovery of RESRAM eligible expenses and increased amortization of prior deferrals increased depreciation and amortization expenses by $5 million.
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Taxes Other Than Income Taxes
| Increase (Decrease) by Segment | ||||||||||||||||||||
Overall Ameren Increase of $10 Million (QTD YoY) | Overall Ameren Increase of $32 Million (YTD YoY) | |||||||||||||||||||
Total by Segment(a) | ||||||||||||||||||||
(a)Includes $2 million, $3 million, $7 million, and $7 million at Ameren Transmission in the three months ended September 30, 2026 and 2025, and in the nine months ended September 30, 2026 and 2025, respectively. Also includes other/intersegment eliminations of $3 million, $2 million, $10 million, and $9 million in the three months ended September 30, 2026 and 2025, and in the nine months ended September 30, 2026 and 2025, respectively.
| Ameren Missouri | Ameren Illinois Natural Gas | Other/Intersegment Eliminations | |||||||||||||||||||||||||||
| Ameren Illinois Electric Distribution | Ameren Transmission | ||||||||||||||||||||||||||||
Taxes other than income taxes increased $10 million and $32 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily because of an increase of $7 million and $25 million, respectively, at Ameren Missouri. The increase at Ameren Missouri is largely due to an increase in property taxes of $12 million in the nine months ended September 30, 2026. Additionally, gross receipts taxes at Ameren Missouri increased $6 million and $12 million, respectively, resulting from an increase in retail electric base rates and sales volumes.
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Other Income, Net
| Increase (Decrease) by Segment | ||||||||||||||||||||
Overall Ameren Increase of $36 Million (QTD YoY) | Overall Ameren Increase of $63 Million (YTD YoY) | |||||||||||||||||||
Total by Segment(a) | ||||||||||||||||||||
(a)Includes $3 million and $4 million at Ameren Illinois Natural Gas in the three months ended September 30, 2026 and 2025, respectively. Also includes $6 million and $(3) million at Ameren Transmission in the three months ended September 30, 2026 and 2025, 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.
Other income, net, increased $36 million and $63 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. In addition to the changes discussed below, other income, net, increased by $18 million and $38 million, respectively, for activity not reported as part of a segment, due to an increase of $24 million and $58 million in income from equity method investments primarily associated with investments to advance innovative energy technologies in the three and nine months ended September 30, 2026. The increase was partially offset by a decrease of $5 million and $15 million, respectively, in the non-service cost component of net periodic benefit income.
Ameren Transmission
Other income, net, increased $9 million and $5 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to an increase of $9 million related to the absence of a 2025 impairment of an equity method investment in the three and nine months ended September 30, 2026.
Ameren Missouri
Other income, net, increased $13 million and $36 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to an increase of $13 million and $43 million, respectively, in the allowance for equity funds used during construction. This increase was partially offset by a decrease of $7 million in the non-service cost component of net periodic benefit income in the nine months ended September 30, 2026.
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Ameren Illinois
Other income, net, decreased $5 million and $21 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to the decrease of $9 million and $20 million, respectively, in the non-service cost component of net periodic benefit income, largely at Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas. Other income, net, decreased $5 million in the nine months ended September 30, 2026, due to lower interest income on regulatory deferrals, primarily at Ameren Illinois Electric Distribution.
Interest Charges
| Increase (Decrease) by Segment | ||||||||||||||||||||
Overall Ameren Increase of $8 Million (QTD YoY) | Overall Ameren Increase of $59 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 $8 million and $59 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods. In addition to changes by segments discussed below, interest charges increased $6 million and $12 million in the three and nine months ended September 30, 2026 at Ameren (parent). The increase is primarily due to issuances net of maturities of long-term debt in March 2025 and March 2026, which increased interest by $4 million and $13 million in the three and nine months ended September 30, 2026, respectively.
Ameren Transmission
Interest charges were comparable between periods.
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Ameren Missouri
Interest charges were comparable in the three months ended September 30, 2026, and increased $32 million in the nine months ended September 30, 2026, compared with the year-ago period. Interest charges in the nine months ended September 30, 2026, increased primarily due to the issuances of long-term debt in February 2026, June 2026, and April 2025, which increased interest expense by $41 million. Additionally, interest charges increased because the PISA and RESRAM were updated when new customer rates became effective on June 1, 2025, pursuant to the April 2025 MoPSC electric rate order. Lower deferrals resulting from the inclusion in base rates of interest associated with certain property, plant, and equipment previously deferred under the PISA and RESRAM increased interest charges by $8 million. These increases were partially offset by an increase in the borrowed funds capitalized as part of the allowance for funds used during construction, which decreased interest charges by $18 million. This was primarily driven by higher average construction work in progress balances.
Ameren Illinois
Interest charges increased $5 million and $17 million in the three and nine months ended September 30, 2026, respectively, compared with the year-ago periods, primarily due to issuances of long-term debt, partially offset by maturities in the nine months ended September 30, 2026. These increased interest expense by $2 million and $7 million at Ameren Illinois Transmission, $3 million and $7 million at Ameren Illinois Electric Distribution, and $1 million and $4 million at Ameren Illinois Natural Gas for the three and nine months ended September 30, 2026, respectively.
Income Taxes
The following table presents effective income tax rates for the three and nine months ended September 30, 2026 and 2025:
Three Months(a) | Nine Months(a) | |||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||
| Ameren | 15 | % | 7 | % | 14 | % | 11 | % | ||||||||||||||||||
| Ameren Missouri | 2 | % | 6 | % | 2 | % | 6 | % | ||||||||||||||||||
| Ameren Illinois | 27 | % | 10 | % | 26 | % | 20 | % | ||||||||||||||||||
Ameren Illinois Electric Distribution | 28 | % | 25 | % | 27 | % | 21 | % | ||||||||||||||||||
Ameren Illinois Natural Gas | 29 | % | 25 | % | 27 | % | 26 | % | ||||||||||||||||||
| Ameren Illinois Transmission | 27 | % | 2 | % | 26 | % | 17 | % | ||||||||||||||||||
| Ameren Transmission | 26 | % | (12) | % | 25 | % | 13 | % | ||||||||||||||||||
(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, 2026 and 2025.
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 higher at Ameren Illinois Electric Distribution in the three and nine months ended September 30, 2026, compared with the year-ago periods, primarily due to a decrease in excess deferred tax amortization pursuant to an ICC order, which was offset by a corresponding increase in electric revenues. The effective tax rate was higher at Ameren Transmission and Ameren Illinois Transmission for the three and nine months ended September 30, 2026, compared with the year-ago periods due to the absence of a revaluation of excess deferred income tax regulatory liabilities in the third quarter of 2025. In 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 applicable to the ratemaking treatment 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. In 2025, the FERC issued an order reflecting implementation of the rules for the other taxpayer who had a similar fact pattern as Ameren Illinois and ATXI. Accordingly, in the third quarter of 2025, Ameren and Ameren Illinois decreased income tax expense by $48 million and $23 million, respectively, to reflect the revaluation of excess deferred income tax regulatory liabilities resulting from TCJA for FERC-regulated jurisdictions pursuant to IRS guidance and a 2025 FERC order.
LIQUIDITY AND CAPITAL RESOURCES
Collections from our utility 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, 2026, there have been no material changes other than in the ordinary course of business related to cash
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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 expected increases in demand, overall system reliability, grid modernization, renewable energy target requirements, 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 2031. Additionally, Ameren may offer and sell from time to time common stock, including under its ATM program, which includes the ability to enter into forward sale agreements, subject to market conditions and other factors. There were no shares issued under the ATM program during the nine months ended September 30, 2026. In August 2026, Ameren increased the amount of common stock available for sale under the ATM program by $2 billion to a total of $5 billion. As of September 30, 2026, Ameren had approximately $2 billion of common stock remaining available for sale under the ATM program. As of September 30, 2026, Ameren had multiple forward sale agreements with various counterparties relating to 19.4 million shares of common stock. In October 2026, Ameren entered into forward sale agreements under the ATM program for 2.1 million shares of common stock. Of these shares, Ameren expects to settle 6.4 million in 2026 and the remaining 15.1 million to fund a portion of its equity needs beyond 2026. Ameren’s equity financing plan is estimated to be approximately $5 billion from 2027 to 2031. This plan includes equity issuances under forward sale agreements, the DRPlus, and employee benefit plans. Ameren expects these issuances to be concentrated primarily near year-end 2027 and year-end 2028 to align with the timing of capital investments and other needs. The Ameren Companies expect their equity to total capitalization and cash flow metrics 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 and forward sale agreements relating to common stock, including those under the ATM program.
The following table presents net cash provided by (used in) operating, investing, and financing activities for the nine months ended September 30, 2026 and 2025:
| Net Cash Provided By Operating Activities | Net Cash Used In Investing Activities | Net Cash Provided By Financing Activities | |||||||||||||||||||||||||||||||||||||||||||||||||||
| 2026 | 2025 | Variance | 2026 | 2025 | Variance | 2026 | 2025 | Variance | |||||||||||||||||||||||||||||||||||||||||||||
| Ameren | $ | 2,193 | (a) | $ | 2,397 | (a) | $ | (204) | $ | (4,154) | $ | (3,112) | $ | (1,042) | $ | 2,066 | $ | 822 | $ | 1,244 | |||||||||||||||||||||||||||||||||
| Ameren Missouri | 1,282 | 1,273 | 9 | (2,820) | (1,875) | (945) | 1,544 | 678 | 866 | ||||||||||||||||||||||||||||||||||||||||||||
| Ameren Illinois | 888 | (a) | 1,117 | (a) | (229) | (1,090) | (1,181) | 91 | 301 | 92 | 209 | ||||||||||||||||||||||||||||||||||||||||||
(a)Both Ameren and Ameren Illinois’ cash provided by operating activities included cash outflows of $92 million and $85 million for the electric energy-efficiency rider and $176 million and $40 million for the customer generation rebate program for the nine months ended September 30, 2026 and 2025, respectively.
Cash Flows from Operating Activities
Our cash, cash equivalents, and restricted 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. For additional information on cash, cash equivalents, and restricted cash, see Note 13 – Supplemental Information under Part I, Item 1, of this report.
Ameren
Ameren’s cash provided by operating activities decreased $204 million in the first nine months of 2026, compared with the year-ago period. The following items contributed to the decrease:
•A $223 million decrease in proceeds received by Ameren Missouri related to production and investment tax credits transferred to unrelated parties.
•A $91 million decrease due to the timing of payments and reimbursements for programs related to customer-owned distributed generation facilities in Ameren Illinois’ service territory.
•A $48 million increase in interest payments, including settlements of interest rate hedges, primarily due to higher average outstanding debt and interest rates on long-term debt.
•A $33 million decrease due to the timing of payments for spent nuclear fuel storage and reimbursements from the DOE.
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•A $30 million increase in non-nuclear energy center maintenance payments, primarily due to increased reliability measures at the Labadie and Sioux energy centers.
•A $26 million increase in pension and postretirement benefit plan contributions.
•An $18 million decrease due to the timing of receipts and refunds of customer deposits.
•An $18 million increase in payments for materials and supplies at Ameren Illinois to support the operational needs of its electric distribution and transmission businesses.
•A $16 million increase in gross receipts tax payments primarily due to an increase in base rates at Ameren Missouri and Ameren Illinois in 2026, compared to 2025.
•A $14 million increase in fuel oil payments to fill new storage tanks at the Audrain Energy Center. Ameren Missouri is converting the energy center to utilize both natural gas and fuel oil.
•A $13 million increase in payments to Ameren Illinois contractors, primarily related to higher costs to comply with expanded programs under the CEJA.
•An $11 million decrease due to the absence of a property tax refund received in 2025 at Ameren Missouri.
•An $8 million increase in payments to fund mitigation programs ordered in the NSR and Clean Air Act litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of the Form 10-K.
The following items partially offset the decrease in Ameren’s cash from operating activities between periods:
•A $203 million increase resulting from higher customer collections, primarily from increased electric and natural gas base rates at Ameren Missouri effective June 1, 2025, and September 1, 2025, respectively, pursuant to MoPSC rate orders, electric distribution and transmission base rate increases at Ameren Illinois, and increased natural gas base rates at Ameren Illinois effective December 2, 2025, pursuant to an ICC rate order. These increases were partially offset by lower customer collections under cost recovery mechanisms.
•An $82 million increase due to the timing of payments for accounts payable and prepaid expenses.
•A $24 million decrease in nuclear refueling and maintenance outage payments related to the Callaway Energy Center. The 2026 outage began in late September 2026, while the previous outage was in spring 2025.
Ameren Missouri
Ameren Missouri’s cash provided by operating activities increased $9 million in the first nine months of 2026, compared with the year-ago period. The following items contributed to the increase:
•A $276 million increase resulting from higher customer collections, primarily from increased electric and natural gas base rates effective June 1, 2025, and September 1, 2025, respectively, pursuant to MoPSC rate orders and higher customer collections under cost recovery mechanisms.
•A $77 million increase due to the timing of payments for accounts payable and prepaid expenses.
•A $49 million increase in income tax refunds from Ameren (parent), pursuant to the tax allocation agreement, primarily due to lower taxable income compared to 2025.
•A $24 million decrease in nuclear refueling and maintenance outage payments related to the Callaway Energy Center. The 2026 outage began in late September 2026, while the previous outage was in spring 2025.
The following items partially offset the increase in Ameren Missouri’s cash from operating activities between periods:
•A $223 million decrease in proceeds received related to production and investment tax credits transferred to unrelated parties.
•A $34 million increase in interest payments primarily due to higher average outstanding debt and interest rates on long-term debt.
•A $33 million decrease due to the timing of payments for spent nuclear fuel storage and reimbursements from the DOE.
•A $30 million increase in non-nuclear energy center maintenance payments, primarily due to increased reliability measures at the Labadie and Sioux energy centers.
•A $14 million increase in fuel oil payments to fill new storage tanks at the Audrain Energy Center. Ameren Missouri is converting the energy center to utilize both natural gas and fuel oil.
•An $11 million decrease due to the absence of a property tax refund received in 2025.
•A $10 million increase in pension and postretirement benefit plan contributions.
•A $10 million decrease due to the timing of receipts and refunds of customer deposits.
•A $10 million increase in gross receipts tax payments primarily due to an increase in base rates in 2026, compared to 2025.
•An $8 million increase in payments to fund mitigation programs ordered in the NSR and Clean Air Act litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of the Form 10-K.
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Ameren Illinois
Ameren Illinois’ cash provided by operating activities decreased $229 million in the first nine months of 2026, compared with the year-ago period. The following items contributed to the decrease:
•A $91 million decrease due to the timing of payments and reimbursements for programs related to customer-owned distributed generation facilities.
•An $84 million decrease due to lower customer collections under cost recovery mechanisms, partially offset by higher customer collections from electric distribution and transmission base rate increases and increased natural gas base rates effective December 2, 2025, pursuant to an ICC rate order.
•A $25 million increase in interest payments primarily due to higher average outstanding debt and interest rates on long-term debt.
•An $18 million increase in payments for materials and supplies to support the operational needs of its electric distribution and transmission businesses.
•A $13 million increase in income tax payments to Ameren (parent), pursuant to the tax allocation agreement, primarily due to higher taxable income compared to 2025.
•A $13 million increase in payments to contractors, primarily due to higher costs to comply with expanded programs under the CEJA.
•An $11 million increase in pension and postretirement benefit plan contributions.
•A $10 million decrease due to the timing of receipts and refunds of customer deposits.
The decrease in Ameren Illinois’ cash from operating activities between periods was partially offset by a $27 million increase due to the timing of payments for accounts payable and prepaid expenses.
Cash Flows from Investing Activities
Ameren’s cash used in investing activities increased $1,042 million during the first nine months of 2026, compared with the year-ago period, primarily as a result of a $971 million increase in capital expenditures, largely resulting from the acquisition of the Split Rail Solar Project and expenditures on other generation projects at Ameren Missouri and electric distribution infrastructure upgrades at Ameren Illinois, partially offset by decreased major storm-related expenditures at Ameren Missouri and decreased expenditures for natural gas infrastructure upgrades related to timing at Ameren Illinois.
Ameren Missouri’s cash used in investing activities increased $945 million during the first nine months of 2026, compared with the year-ago period, primarily as a result of an $877 million increase in capital expenditures, largely resulting from the acquisition of the Split Rail Solar Project and expenditures on other generation projects, partially offset by decreased storm-related expenditures, and a $43 million increase due to net money pool advances.
Ameren Illinois’ cash used in investing activities decreased $91 million during the first nine months of 2026, compared with the year-ago period, as a result of a $51 million decrease in net money pool advances and a $39 million decrease in capital expenditures, primarily related to decreases in transmission infrastructure upgrades and the timing of natural gas infrastructure upgrades, partially offset by an increase in electric distribution infrastructure upgrades.
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Capital Expenditures
The following table presents Ameren’s estimate of capital expenditures that will be incurred from 2026 through 2031, including construction expenditures and allowance for funds used during construction. The estimated 2026 to 2030 capital expenditures have significantly increased compared to those estimates disclosed in the Form 10-K, to better align with Ameren Missouri’s 2026 PRP filed in September 2026 and to include a portion of the MISO long-range transmission competitive bid projects awarded to ATXI in 2026.
| 2026 | 2027 - 2031 | Total | |||||||||||||||||||||||||||
| Ameren Missouri | $ | 4,000 | $ | 24,650 | - | $ | 27,250 | $ | 28,650 | - | $ | 31,250 | |||||||||||||||||
| Ameren Illinois Electric Distribution | 720 | 3,510 | - | 3,880 | 4,230 | - | 4,600 | ||||||||||||||||||||||
| Ameren Illinois Natural Gas | 335 | 1,785 | - | 1,975 | 2,120 | - | 2,310 | ||||||||||||||||||||||
| Ameren Illinois Transmission | 410 | 2,905 | - | 3,215 | 3,315 | - | 3,625 | ||||||||||||||||||||||
| ATXI and other electric transmission subsidiaries | 475 | 3,310 | - | 3,675 | 3,785 | - | 4,150 | ||||||||||||||||||||||
| Other | 5 | 40 | - | 45 | 45 | - | 50 | ||||||||||||||||||||||
| Ameren | $ | 5,945 | $ | 36,200 | - | $ | 40,040 | $ | 42,145 | - | $ | 45,985 | |||||||||||||||||
Ameren Missouri’s estimated capital expenditures include transmission, distribution, grid modernization, and generation-related investments, primarily natural gas, renewable generation, battery energy storage, and fuel cells, consistent with investments outlined in the 2026 PRP through 2031 to maintain reliability and address load growth opportunities based on the 2.8 gigawatts of demand from large load customers under electric service agreements. Ameren Illinois’ estimated capital expenditures are primarily for electric and natural gas transmission and distribution-related investments.
Ameren Missouri continually reviews its generation portfolio and expected power needs, including estimates of future load growth. As a result, Ameren Missouri could modify its plan for generation capacity, the type of generation asset technology that will be employed, and whether capacity or power may be purchased, among other changes. Additionally, we continually review the reliability of our transmission and distribution systems, expected capacity needs, and opportunities for transmission investments within and outside our service territories. The timing and amount of investments could vary because of changes in expected capacity, the condition of transmission and distribution systems, future rate orders, and our ability and willingness to pursue transmission investments, as well as our ability to obtain necessary regulatory approvals, among other factors. Any changes in future generation, transmission, or distribution needs could result in significant changes in capital expenditures or losses, which could be material. Compliance with environmental regulations could also have significant impacts on the level of capital expenditures.
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.
Ameren’s cash provided by financing activities increased $1.2 billion during the first nine months of 2026, compared with the year-ago period. During the first nine months of 2026, Ameren utilized net proceeds from the issuance of long-term debt of $3.2 billion to repay then-outstanding short-term debt, including short-term debt incurred to refinance $350 million of long-term debt maturities, and for general corporate purposes. Ameren also repaid net short-term debt of $147 million. In comparison, during the first nine months of 2025, Ameren utilized net proceeds from the issuance of long-term debt of $2.0 billion for general corporate purposes, and to repay $300 million of long-term debt maturities and then-outstanding short-term debt. In addition, during the first nine months of 2025, Ameren also repaid net short-term debt of $239 million. During the first nine months of 2026, Ameren paid common stock dividends of $622 million, compared with $576 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 $866 million during the first nine months of 2026, compared with the year-ago period. During the first nine months of 2026, Ameren Missouri utilized net proceeds from the issuance of long-term debt of $1.4 billion to repay then-outstanding short-term debt, including net commercial paper of $371 million. Additionally, during the first nine months of 2026, Ameren Missouri utilized capital contributions from Ameren (parent) of $550 million, and cash provided by operating activities to fund, in part, capital expenditures. In comparison, during the first nine months of 2025, Ameren Missouri utilized net proceeds from the issuance of long-term debt of $500 million to repay then-outstanding short-term debt. In addition, during the first nine months of 2025, Ameren Missouri utilized proceeds from net commercial paper issuances of $259 million, money pool borrowings of $51 million, and cash provided by operating activities to fund, in part, capital expenditures. During the first nine months of 2025, Ameren Missouri paid common stock dividends of $125 million.
Ameren Illinois’ cash provided by financing activities increased $209 million during the first nine months of 2026, compared with the year-ago period. During the first nine months of 2026, Ameren Illinois utilized net proceeds from the issuance of long-term debt of $400 million to repay then-outstanding short-term debt. In addition, Ameren Illinois utilized proceeds from net commercial paper issuances of
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$171 million and cash provided by operating activities to fund, in part, capital expenditures. In comparison, during the first nine months of 2025, Ameren Illinois utilized proceeds from the issuance of long-term debt of $711 million to repay $300 million of long-term debt maturities and then-outstanding short-term debt. Ameren Illinois also repaid net commercial paper borrowings of $88 million and money pool borrowings of $37 million. During the first nine months of 2026, Ameren Illinois also paid common stock dividends of $265 million, compared with $185 million in the year-ago period.
See Long-term Debt and Equity in this section for additional information on maturities and issuances of long-term debt, and issuances of common stock.
Short-term Debt and Liquidity
The following table presents Ameren’s consolidated net available liquidity as of September 30, 2026:
Available at September 30, 2026 | |||||
| Ameren (parent) and Ameren Missouri: | |||||
Missouri Credit Agreement – borrowing capacity | $ | 1,900 | |||
| Less: Ameren (parent) commercial paper outstanding | 122 | ||||
Less: Ameren Missouri commercial paper outstanding | 100 | ||||
| Less: Letters of credit | 30 | ||||
Missouri Credit Agreement – subtotal | 1,648 | ||||
| Ameren (parent) and Ameren Illinois: | |||||
Illinois Credit Agreement – borrowing capacity | 1,300 | ||||
| Less: Ameren (parent) commercial paper outstanding | 86 | ||||
Less: Ameren Illinois commercial paper outstanding | 188 | ||||
| Less: Letters of credit | 4 | ||||
Illinois Credit Agreement – subtotal | 1,022 | ||||
Subtotal | $ | 2,670 | |||
Add: Cash and cash equivalents | 40 | ||||
Net Available Liquidity(a) | $ | 2,710 | |||
(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.
The Credit Agreements, among other things, provide $3.2 billion of credit until maturity in December 2030. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on the Credit Agreements. 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 2025, the FERC issued orders authorizing ATXI to issue up to $500 million of short-term debt securities through January 2027. In December 2025, the FERC issued orders authorizing Ameren Missouri and Ameren Illinois to issue up to $1.6 billion and $1.1 billion, respectively, of short-term debt securities through December 2027.
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 the existing Credit Agreements or to other borrowing arrangements, or other arrangements may be made.
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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 redemptions and maturities of long-term debt for the nine months ended September 30, 2026 and 2025:
| Month Issued, Redeemed, or Matured | 2026 | 2025 | ||||||||||||||||||
| Issuances of Long-term Debt | ||||||||||||||||||||
| Ameren: | ||||||||||||||||||||
| 5.375% Senior unsecured notes due 2035 | March | $ | — | $ | 749 | |||||||||||||||
| 5.00% Senior unsecured notes due 2036 | March | 399 | — | |||||||||||||||||
Junior subordinated notes due 2057(a) | September | 900 | — | |||||||||||||||||
| Ameren Missouri: | ||||||||||||||||||||
| 4.80% First mortgage bonds due 2036 | February | 450 | — | |||||||||||||||||
| 5.55% First mortgage bonds due 2056 | February | 448 | — | |||||||||||||||||
| 5.25% First mortgage bonds due 2035 | April | — | 500 | |||||||||||||||||
| 5.75% First mortgage bonds due 2056 | June | 497 | — | |||||||||||||||||
| Ameren Illinois: | ||||||||||||||||||||
| 5.625% First mortgage bonds due 2055 | March | — | 350 | |||||||||||||||||
| 5.50% First mortgage bonds due 2036 | August | 400 | ||||||||||||||||||
| 5.625% First mortgage bonds due 2055 | September | — | 361 | |||||||||||||||||
| ATXI: | ||||||||||||||||||||
| 5.83% Senior unsecured notes due 2041 | August | 140 | — | |||||||||||||||||
| Total Ameren long-term debt issuances | $ | 3,234 | $ | 1,960 | ||||||||||||||||
| Issuances of Common Stock | ||||||||||||||||||||
| Ameren: | ||||||||||||||||||||
DRPlus and 401(k)(b)(c) | Various | $ | 31 | $ | 35 | |||||||||||||||
Total Ameren common stock issuances(d) | $ | 31 | $ | 35 | ||||||||||||||||
| Maturities of Long-term Debt | ||||||||||||||||||||
| Ameren: | ||||||||||||||||||||
| 3.65% Senior unsecured notes due 2026 | February | $ | 350 | $ | — | |||||||||||||||
| Ameren Missouri: | ||||||||||||||||||||
4.85% Securitized utility tariff bonds due 2039(e) | April | 12 | — | |||||||||||||||||
| Ameren Illinois: | ||||||||||||||||||||
| 3.25% Senior secured notes due 2025 | March | — | 300 | |||||||||||||||||
| Total Ameren long-term debt maturities | $ | 362 | (f) | $ | 300 | (f) | ||||||||||||||
(a)The junior subordinated notes will pay interest at a fixed annual rate of 6.45% until March 15, 2032. After that date, the interest rate will be reset every five years to the applicable five-year United States Treasury rate plus 1.868%, subject to a minimum rate of 6.45%.
(b)Ameren issued a total of 0.3 million and 0.3 million shares of common stock under its DRPlus and 401(k) plan for the nine months ended September 30, 2026 and 2025, respectively.
(c)Excludes a $6 million and $7 million receivable at September 30, 2026 and 2025, respectively.
(d)Excludes 0.2 million and 0.3 million shares of common stock valued at $25 million and $25 million issued for no cash consideration in connection with stock-based compensation for the nine months ended September 30, 2026 and 2025, respectively.
(e)These securitized utility tariff bonds were issued by AMF. The securitized tariff bondholders have no recourse to Ameren Missouri.
(f)Excludes Ameren (parent)’s purchases of senior secured notes and first mortgage bonds issued by Ameren Missouri and first mortgage bonds issued by Ameren Illinois for $16 million and $24 million in aggregate for the nine months ended September 30, 2026 and 2025, respectively.
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, and the ATM program.
Indebtedness Provisions and Other Covenants
At September 30, 2026, 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.
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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, and 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 45% and 55% 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, 2026, 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, 2026 and 2025:
| Nine Months | |||||||||||
| 2026 | 2025 | ||||||||||
| Ameren | $ | 622 | $ | 576 | |||||||
| Ameren Missouri | — | 125 | |||||||||
| Ameren Illinois | 265 | 185 | |||||||||
| ATXI | 40 | 49 | |||||||||
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 were $70 million for Ameren and Ameren Missouri and cash collateral posted by external parties was $154 million, $67 million, and $87 million for Ameren, Ameren Missouri, and Ameren Illinois at September 30, 2026. A sub-investment-grade issuer or senior unsecured debt rating (below “Baa3” from Moody’s or below “BBB-” from S&P) at September 30, 2026, 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 $120 million, $54 million, and $66 million, respectively.
Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at September 30, 2026, if market prices were 15% higher or lower than September 30, 2026 levels in the next 12 months and 20% higher or lower thereafter through the end of the term of the commodity contracts, then Ameren and Ameren Missouri could be required to post $47 million 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 2026 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 PPRA became effective in 2025. The law made modifications to integrated resource planning, which requires Missouri electric utilities to file plans for meeting their customers' long-term energy needs. By August 2027, the MoPSC will publish a schedule for
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Missouri electric utilities to file integrated resource plans every four years. The MoPSC will be required to issue an order on the plans and shall determine whether the electric utility has submitted sufficient documentation and selected preferred resource plans representing a reasonable and prudent means of serving the utility's load obligations at just and reasonable rates. If the MoPSC approves the plans, requests for CCNs for new generation facilities to be constructed or acquired as a part of the approved plans shall be deemed necessary and convenient and the scope of the CCN proceedings to review projects will be limited. The approved generation facilities will also be eligible to include construction work in progress in rate base, subject to MoPSC approval, which would improve the timeliness of cash recovery. Utilities are not allowed to capitalize allowance for funds used during construction on amounts included in rate base under this provision. The amount of construction work in progress to be included in rate base is limited to prudently incurred expenditures made within the construction period for the facility. Separately, outside of the integrated resource planning process discussed above, the law allows a Missouri electric utility to request that the MoPSC authorize the inclusion of construction work in progress for new natural gas-fired generation facilities in rate base, subject to the same restrictions discussed above. The provisions allowing for the inclusion of construction work in progress on natural gas-fired generation in rate base expire in December 2035, unless Ameren Missouri requests and receives MoPSC approval of an extension through 2045. Also, the law allows natural gas utilities to file regulatory rate reviews using a future test year, subject to MoPSC approval. The law also made modifications to the PISA and requires electric utilities to submit service tariff schedules for certain large load customers as discussed below.
•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 generation facilities and service to new customer premises. Additionally, the PISA permits Ameren Missouri to earn a return at the applicable WACC on 85% of 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. Also, 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. 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. Pursuant to the PPRA discussed above, Ameren Missouri’s PISA election was extended through 2035 and an additional extension through 2040 is allowed if requested by Ameren Missouri and approved by the MoPSC. This law also reduced the 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 annual limit in effect was 2.5% and changed to 2.25%, prorated monthly, for revenue requirements approved by the MoPSC after August 2025. Ameren Missouri expects significantly higher allowance for equity funds used during construction and investments in infrastructure eligible for PISA in 2026, compared to 2025, and in 2027, compared to 2026.
•In June 2026, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $343 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 2027 and new rates effective by June 2027. 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.
•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 2027 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are $749 million and $319 million, respectively. These revenue requirements represent increases in Ameren Illinois’ and ATXI’s revenue requirements of $64 million and $53 million, respectively, from the revenue requirements reflected in 2026 rates, primarily due to higher expected rate base. These rates will affect Ameren Illinois’ and ATXI’s cash receipts during 2027, but do not determine their respective electric transmission service operating revenues, which instead are based on 2027 actual recoverable costs, rate base, and a return on rate base at the applicable WACC as calculated under the FERC formula ratemaking framework.
•In 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 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 $19 million and $14 million, respectively,
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based on each company’s 2026 projected rate base.
•Pursuant to the CEJA, 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’ 2026 electric distribution service revenues are based on its 2026 actual recoverable costs, 2026 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. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the applicable annual period. Additionally, the RBA ensures electric distribution service revenues are decoupled from sales volumes and wholesale and miscellaneous revenue differences from those assumed in the revenue requirement approved by the ICC. The RBA remains effective whether Ameren Illinois elects to file an MYRP or a traditional regulatory rate review. In April 2026, Ameren Illinois filed a reconciliation adjustment to its 2025 electric distribution service revenue requirement with the ICC. In August 2026, Ameren Illinois updated its reconciliation adjustment, requesting recovery of $28 million. The adjustment reflects Ameren Illinois’ actual 2025 recoverable costs, 2025 year-end rate base, and a capital structure composed of 50% common equity. An ICC decision is required by December 2026, and any approved adjustment would be collected from customers in 2027.
•In December 2024, the ICC issued an order in connection with a revised Grid Plan and a revised MYRP filed by Ameren Illinois in March 2024, approving revenue requirements for electric distribution services for 2024 through 2027 of $1,206 million, $1,287 million, $1,367 million, and $1,421 million, respectively. Using the 2023 revenue requirement as a starting point, the approved revenue requirements in the ICC’s December 2024 order represent a cumulative four-year increase of $308 million.
•In January 2026, the CRGA was enacted and became effective in June 2026. The law includes certain provisions that affect Ameren Illinois’ annual investments in energy-efficiency programs, and the related return on those investments. Under the law, the annual spending cap for energy-efficiency investments increased for 2027, 2028, and 2029. As a result, in May 2026, Ameren Illinois filed an electric energy efficiency plan with the ICC, which includes annual investments in electric energy-efficiency programs up to $192 million, $239 million, and $276 million for 2027, 2028, and 2029, respectively. A decision by the ICC in this proceeding is expected in November 2026. In addition, Ameren Illinois expects the ROE component of the applicable WACC used to calculate its return on energy-efficiency investments for the year to change in 2027 to that year’s ICC-approved ROE for Ameren Illinois’ electric distribution service. The ROE will continue to be increased or decreased based on the achievement of certain goals as discussed below. For 2027, the allowed ROE will be the ICC-approved 8.72% from Ameren Illinois’ MYRP electric distribution service regulatory rate review.
•Pursuant to Illinois law, Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC. Ameren Illinois expects the ROE component of the applicable WACC to be based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points through 2026. 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 and demand goals. While the ICC has approved a plan for Ameren Illinois to invest approximately $126 million per year in electric energy-efficiency programs through 2029, 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 Ameren Illinois’ investments in electric energy-efficiency programs. Pursuant to the CRGA, Ameren Illinois filed an updated energy-efficiency plan for 2027 through 2029 as discussed above.
•In November 2025, the ICC issued an order in Ameren Illinois’ January 2025 natural gas delivery service regulatory rate review, which resulted in an increase to Ameren Illinois’ annual revenues for natural gas delivery service of $79 million. The order reflected a reduction of $75 million of planned distribution and transmission capital investments included in Ameren Illinois’ future test year request. The new rates became effective in December 2025. In January 2026, Ameren Illinois filed an appeal of the ICC’s November 2025 order to the Illinois Appellate Court for the Fifth Judicial District. The appeal challenged the inclusion of the non-service cost component of the net periodic benefit income related to other postretirement benefits in the annual revenue requirement and the $75 million reduction of planned capital investments, among other things. The court is under no deadline to address the appeal, and Ameren Illinois cannot predict the ultimate outcome of the appeal.
•A November 2023 ICC order directed the ICC staff to develop a plan for a future of gas proceeding. All of the Illinois natural gas utilities subject to ICC regulation are included in this proceeding, which is exploring issues involving the decarbonization of the natural gas distribution system in light of the state of Illinois’ goal of economy-wide 100% clean energy by 2050, pursuant to the CEJA. Some of the
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issues being addressed include the mitigation of any natural gas distribution stranded assets, the role of energy efficiency in decarbonization, and the associated impacts of natural gas decarbonization to the electric distribution system, among others. A final ICC staff report is expected in 2026 and will be used by the ICC to guide further action, if any.
•Ameren Missouri’s scheduled refueling and maintenance outage at its Callaway Energy Center began in late September 2026, and the energy center is expected to return to service in November 2026. The next refueling and maintenance outage is scheduled for the spring of 2028. 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.
•Ameren Missouri and Ameren Illinois continue to make infrastructure investments to meet customer needs 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 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, 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 battery energy storage. We expect a net increase in demand resulting from the electrification of the economy, including in the transportation sector. In addition, several entities in various industries are considering either locating or expanding their operations within our service territories. In 2026, Ameren Missouri executed electric service agreements with large load customers under its modified large primary service tariff that was approved in 2025, representing 2.8 gigawatts of demand that is expected to begin materializing in the second half of 2027 and to reach full capacity in 2030. Construction agreements have been signed with developers representing an additional 1.2 gigawatts of demand that has not been secured through electric service agreements. Serving increased demand due to electrification, new customers, and other growth will require increased investments, including future investments for system reliability improvements and new generation sources, which will result in rate base growth, and higher purchased power costs in the future until new generation is placed in service. Ameren Missouri’s purchased power costs are part of the net energy costs recoverable under the FAC, with 95% of the variance between net energy costs and the amount set in base rates recovered or refunded through the FAC.
Liquidity and Capital Resources
•As discussed above, Ameren Missouri has executed electric service agreements with large load customers in 2026, and several other entities in various industries are considering either locating or expanding their operations within Ameren Missouri’s service territory. In order to address these load growth opportunities and maintain reliability, Ameren Missouri filed its preferred resource plan with the MoPSC in September 2026. Ameren’s ambition is to achieve net-zero carbon emissions by 2045; however, it will no longer maintain interim emissions-reduction goals. Achieving net-zero carbon emissions will be dependent on a variety of factors, including cost-effective advancements in innovative energy and carbon-capture technologies and constructive federal and state energy and economic policies. The 2026 PRP includes, among other things, the following:
•estimated total load growth of 2.9 gigawatts by 2030, 5 gigawatts by 2035, and 6 gigawatts by 2045;
•adding 2,100 MWs of natural gas-fired combined-cycle generation by 2031, which are expected to be achieved through the West Alton Natural Gas Project discussed in Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report, an additional 2,800 MWs by 2035, and an additional 1,400 MWs by 2042;
•adding 1,900 MWs of natural gas-fired simple-cycle generation by 2029, which includes the Big Hollow and Castle Bluff natural gas generation projects discussed in Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report, and an additional 2,400 MWs by 2045;
•adding 500 MWs of natural gas fuel cells by 2030;
•adding 1,300 MWs of solar generation by 2030, which includes the Reform, Tom Sawyer, and Ringer solar generation projects discussed in Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report, an additional 1,050 MWs by 2035, and an additional 1,250 MWs by 2045;
•adding 1,500 MWs of wind generation by 2040;
•adding 2,400 MWs of battery energy storage by 2030, which includes the battery energy storage projects discussed in Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report;
•adding 1,200 MWs of nuclear generation by 2040;
•retiring all of Ameren Missouri’s coal-fired energy centers by 2042;
•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
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•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.
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 state or federal approvals for the addition of renewable resources, battery energy storage, nuclear or natural gas-fired generation, or natural gas fuel cells, retirement of energy centers, and new or continued customer energy-efficiency programs; the ability to enter into agreements for renewable, natural gas-fired, or nuclear generation, natural gas fuel cells, or battery energy storage and acquire or construct those resources at a reasonable cost; the ability of suppliers, contractors, and developers to meet contractual commitments and complete projects timely, 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 enter into natural gas supply agreements at reasonable prices and adequate quantities to power Ameren Missouri’s natural gas-fired energy centers; the continued existence and ability to qualify for, and use or transfer, federal production or investment tax credits; the ability to maintain system reliability; new and/or changes in environmental regulations, including those related to CO2 and other greenhouse gas emissions; energy and capacity 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. Also, changes to capacity accreditation rules adopted by the MISO could reduce the accredited capacity of renewable generation and battery energy storage and increase regional capacity prices, potentially requiring additional investment and higher costs to satisfy resource adequacy requirements. In addition, recent changes in federal domestic energy policy, including low cost financing programs for certain fossil fuel-fired generation projects, have reflected increased investment in fossil fuel infrastructure. This change could impact Ameren Missouri’s ability to construct and/or acquire renewable energy generation facilities and battery energy storage. Ameren Missouri expects to file its next preferred resource plan in September 2029.
•Through 2031, 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, as well as generation and battery energy storage facilities, consistent with investments outlined in the 2026 PRP discussed above to maintain reliability and address load growth opportunities based on the 2.8 gigawatts of demand from large load customers under electric service agreements. We estimate that we will invest up to $46.0 billion (Ameren Missouri – up to $31.3 billion; Ameren Illinois – up to $10.5 billion; ATXI – up to $4.2 billion) of capital expenditures from 2026 through 2031. These estimates include the first tranche MISO long-range transmission projects assigned to Ameren, the first tranche competitive projects awarded to ATXI, a portion of the second tranche projects assigned to Ameren, and a portion of the second tranche competitive projects awarded to ATXI, all of which are discussed below.
•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 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 construction in 2024, with forecasted completion dates near the end of this decade. In addition, the MISO awarded three competitive bid projects to ATXI and another owner that represent a total estimated investment of approximately $250 million for ATXI. Also in 2024, the MISO approved a first set of second tranche projects. A portion of these projects were assigned to Ameren and are estimated to cost approximately $1.3 billion, based on the MISO’s cost estimate. Related to these projects, Ameren expects to begin construction in mid-2028, with forecasted completion dates early in the next decade. The first set of second tranche projects also includes competitive bid projects. In 2026, the MISO awarded three of these competitive bid projects to ATXI and other joint owners that represent a total estimated investment of approximately $1.2 billion for ATXI, based on the MISO’s cost estimate. In August 2026, the FERC approved transmission rate incentives relating to two of these competitive bid projects. The incentives will allow construction work in progress to be included in rate base, thereby improving the timeliness of cash recovery, and will allow recovery of prudently incurred costs, subject to FERC approval, for any portion of the projects if they are abandoned for reasons beyond the control of ATXI. Since construction work in progress will be included in rate base and earn a return, ATXI will not capitalize allowance for funds used during construction on these projects.
•In 2025, the presidential administration issued several executive orders on environmental regulations and enforcement. Many of these actions require further implementation by the EPA, and some of these actions will likely be subject to further judicial review. Grid reliability, environmental, or other regulations, including those related to CO2 or other emissions, or other executive orders or actions taken by federal or state regulators, including federal orders related to planned retirements of coal-fired power plants, could result in significant changes 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. The ultimate implementation of any of these new regulations, as well as the timing of any such implementation, is uncertain. 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
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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 $3.2 billion of credit through December 2030, 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 $4.0 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 2026 to 2031 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, including under the ATM program, and issuances and maturities of long-term debt in 2026 through the date of this report. Ameren (parent) entered into interest rate swaps to hedge interest rate risk on certain forecasted interest payments associated with debt issuances in 2026 and 2027. 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, 2026, for Ameren. 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 2031. Additionally, Ameren may offer and sell from time to time common stock, including under its ATM program, which includes the ability to enter into forward sale agreements, subject to market conditions and other factors. In August 2026, Ameren increased the amount of common stock available for sale under the ATM program by $2 billion to a total of $5 billion. As of September 30, 2026, Ameren had approximately $2 billion of common stock remaining available for sale under the ATM program. As of September 30, 2026, Ameren had multiple forward sale agreements with various counterparties relating to 19.4 million shares of common stock. In October 2026, Ameren entered into forward sale agreements under the ATM program for 2.1 million shares of common stock. Of these shares, Ameren expects to settle 6.4 million in 2026 and the remaining 15.1 million to fund a portion of its equity needs beyond 2026. Ameren’s equity financing plan is estimated to be approximately $5 billion from 2027 to 2031. This plan includes equity issuances under forward sale agreements, the DRPlus, and employee benefit plans. Ameren expects these issuances to be concentrated primarily near year-end 2027 and year-end 2028 to align with the timing of capital investments and other needs. The Ameren Companies expect their equity to total capitalization and cash flow metrics 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).
•Pursuant to the IRA and the OBBBA, Ameren Missouri expects to transfer production and investment tax credits to unrelated parties in an aggregate amount of approximately $2.9 billion from 2026 to 2031. Proceeds from these transfers are included in Ameren Missouri’s tracker related to production and investment tax credits allowed under the IRA and the OBBBA or the RESRAM and are ultimately refunded to customers.
•As of September 30, 2026, Ameren had $339 million in tax benefits from federal and state income tax credit carryforwards, $115 million in tax benefits from federal and state net operating loss carryforwards, $20 million in tax receivables, which will be utilized in future periods, and $47 million in receivables related to production and investment tax credits to be transferred to third parties. 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. Ameren expects annual federal income tax payments to be immaterial through 2031.
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.
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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.
ITEM 4. CONTROLS AND PROCEDURES.
(a)Evaluation of Disclosure Controls and Procedures
As of September 30, 2026, 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, 2026, 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 reasonable 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, 2026, to September 30, 2026.
ITEM 5. OTHER INFORMATION.
Insider Adoption or Termination of Trading Arrangements
During the fiscal quarter ended September 30, 2026, none of our directors or officers informed us of the adoption or termination
On August 6, 2026 , Theresa A. Shaw , Senior Vice President, Chief Accounting and Transformation Officer of Ameren , adopted a Rule 10b5-1 trading arrangement that provides for the sale of up to an aggregate of approximately 7,640 shares, consisting of:
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•up to 500 shares on a quarterly basis between November 2026 and November 2027, subject to certain price limitations set forth in the trading arrangement; and
•shares acquired upon vesting of certain equity awards, consisting of (i) 100% of shares delivered from the 2024 restricted stock units award scheduled to vest on March 1, 2027 (approximately 1,692 shares before applicable tax withholding), and (ii) 5% of shares delivered from the 2024 performance condition performance share units and 2024 market condition performance share units awards scheduled to vest on March 1, 2027 (approximately 564 shares and 3,384 shares, respectively, before applicable performance adjustments and tax withholding).
Ms. Shaw’s 10b5-1 trading arrangement will terminate on the earlier of: (i) November 16, 2027 ; (ii) execution of all trades or expiration of all orders relating to such trades under the Rule 10b5-1 trading arrangement; or (iii) such date as the Rule 10b5-1 trading arrangement is otherwise terminated according to its terms.
The trading arrangement discussed above is intended to satisfy the affirmative defense conditions of Rule 10b5-1(c).
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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: | |||||||||||||||||
| Instruments Defining Rights of Security Holders, Including Indentures | ||||||||||||||||||||
| 4.1 | Ameren Ameren Illinois | Supplemental Indenture to the Ameren Illinois Mortgage, dated August 1, 2026, for 5.50% First Mortgage Bonds due 2036 | August 24, 2026 Form 8-K, Exhibit 4.2, File No. 1-3672 | |||||||||||||||||
| 4.2 | Ameren | Note Purchase Agreement, dated as of August 6, 2026, between Ameren Transmission Company of Illinois and the several purchasers named therein | ||||||||||||||||||
| 4.3 | Ameren | Indenture, dated as of September 1, 2026, from Ameren to The Bank of New York Mellon Trust Company, N.A., as trustee, relating to subordinated debt securities | September 18, 2026 Form 8-K, Exhibit 4.1, File No. 1-14756 | |||||||||||||||||
| 4.4 | Ameren | Company Order, dated September 18, 2026, establishing the Junior Subordinated Notes due 2057 (including the global notes) | September 18, 2026 Form 8-K, Exhibits 4.2 and 4.3, 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) | ||||||||||||||||||
*Compensatory plan or arrangement.
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/ Leonard P. Singh | ||
| Leonard P. Singh Executive Vice President and Chief Financial Officer (Principal Financial Officer) | ||
| UNION ELECTRIC COMPANY (Registrant) | ||
| /s/ Leonard P. Singh | ||
| Leonard P. Singh Executive Vice President and Chief Financial Officer (Principal Financial Officer) | ||
| AMEREN ILLINOIS COMPANY (Registrant) | ||
| /s/ Leonard P. Singh | ||
| Leonard P. Singh Executive Vice President and Chief Financial Officer (Principal Financial Officer) | ||
Date: November 6, 2026
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