0001002910us-gaap:ElectricityMemberus-gaap:IntersegmentEliminationMember2023-01-012023-06-30

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 ~~March 31,~~June 30, 2023


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


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

(Missouri Corporation)

1901 Chouteau Avenue

St. Louis, Missouri 63103

(314) 621-3222


1-2967			Union Electric Company			43-0559760

(Missouri Corporation)

1901 Chouteau Avenue

St. Louis, Missouri 63103

(314) 621-3222


1-3672			Ameren Illinois Company			37-0211380

(Illinois Corporation)

10 Richard Mark Way

Collinsville, Illinois 62234

(618) 343-8150

Securities Registered Pursuant to Section 12(b) of the Act:


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

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Indicate by check mark whether the registrants: (1) have 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) have been subject to such filing requirements for the past 90 days.

Ameren Corporation

Yes

☒

☐

Union Electric Company

Yes

☒

☐

Ameren Illinois Company

Yes

☒

☐

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

Ameren Corporation

Yes

☒

☐

Union Electric Company

Yes

☒

☐

Ameren Illinois Company

Yes

☒

☐

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

Ameren Corporation

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

Union Electric Company

Large accelerated filer

☐

Accelerated filer

☐

Non-accelerated filer

☒

Smaller reporting company

☐

Emerging growth company

☐

Ameren Illinois Company

Large accelerated filer

☐

Accelerated filer

☐

Non-accelerated filer

☒

Smaller reporting company

☐

Emerging growth company

☐

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


Ameren Corporation			☐
Union Electric Company			☐
Ameren Illinois Company			☐

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

Ameren Corporation

Yes

☐

☒

Union Electric Company

Yes

☐

☒

Ameren Illinois Company

Yes

☐

☒

The number of shares outstanding of each registrant’s classes of common stock as of ~~April 28,~~July 31, 2023, was as follows:


Registrant	Title of each class of common stock	Shares outstanding
Ameren Corporation	Common stock, $0.01 par value per share	~~262,609,472~~262,749,535
Union Electric Company	Common stock, $5 par value per share, held by Ameren Corporation	102,123,834
Ameren Illinois Company	Common stock, no par value, held by Ameren Corporation	25,452,373

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

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TABLE OF CONTENTS


		Page
Glossary of Terms and Abbreviations		1

Forward-looking Statements		1

PART I. Financial Information

Item 1.	Financial Statements (Unaudited)	4
	Ameren Corporation	4
	Consolidated Statement of Income and Comprehensive Income	4

	Consolidated Balance Sheet	5
	Consolidated Statement of Cash Flows	6
	Consolidated Statement of Shareholders’ Equity	7
	Union Electric Company (d/b/a Ameren Missouri)	8
	Consolidated Statement of Income	8
	Consolidated Balance Sheet	9
	Consolidated Statement of Cash Flows	10
	Consolidated Statement of Shareholders’ Equity	11
	Ameren Illinois Company (d/b/a Ameren Illinois)	12
	Statement of Income	12
	Balance Sheet	13
	Statement of Cash Flows	14
	Statement of Shareholders’ Equity	15
	Note 1. Summary of Significant Accounting Policies	16
	Note 2. Rate and Regulatory Matters	1617
	Note 3. Short-term Debt and Liquidity	1920
	Note 4. Long-term Debt and Equity Financings	2021
	Note 5. Other Income, Net	2223
	Note 6. Derivative Financial Instruments	2223
	Note 7. Fair Value Measurements	2425
	Note 8. Related-party Transactions	2728
	Note 9. Commitments and Contingencies	2829
	Note 10. Callaway Energy Center	3133
	Note 11. Retirement Benefits	3234
	Note 12. Income Taxes	3335
	Note 13. Supplemental Information	3335
	Note 14. Segment Information	3638
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3842
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	6676
Item 4.	Controls and Procedures	6676

PART II. Other Information

Item 1.	Legal Proceedings	6776
Item 1A.	Risk Factors	6777
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6777
Item 5.	Other Information	77
Item 6.	Exhibits	6878

Signatures		6979

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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.

CCN – Certificate of convenience and necessity.

Form 10-K – The combined Annual Report on Form 10-K for the year ended December 31, 2022, filed by the Ameren Companies with the SEC.

QTD – Three months ended June 30.

YTD – Six months ended June 30.

YoY – Compared with the year-ago period.

FORWARD-LOOKING STATEMENTS

Statements in this report not based on historical facts are considered “forward-looking” and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such forward-looking statements have been made in good faith and are based on reasonable assumptions, there is no assurance that the expected results will be achieved. These statements include (without limitation) statements as to future expectations, beliefs, plans, projections, strategies, targets, estimates, objectives, events, conditions, and financial performance. In connection with the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause actual results to differ materially from those anticipated. The following factors, in addition to those discussed within Risk Factors in the Form 10-K, and elsewhere in this report and in our other filings with the SEC, could cause actual results to differ materially from management expectations suggested in such forward-looking statements:

•regulatory, judicial, or legislative actions, and any changes in regulatory policies and ratemaking determinations, that may change regulatory recovery mechanisms, such as those that may result from the impact of a final ruling to be issued by the United States District Court for the Eastern District of Missouri regarding its September 2019 remedy order for the Rush Island Energy Center, the MoPSC staff review of the planned Rush Island Energy Center retirement, Ameren Missouri’s ~~electric regulatory rate review filed in August 2022 with the MoPSC, Ameren Missouri’s proposed customer energy-efficiency plan under the~~nonunanimous stipulation and agreement related to MEEIA 2019 filed with the MoPSC in ~~March~~August 2023, Ameren Illinois’ MYRP electric distribution service regulatory rate review filed in January 2023 with the ICC, Ameren Illinois’ natural gas regulatory rate review filed in January 2023 with the ICC, Ameren Illinois’ electric distribution service revenue requirement reconciliation adjustment request filed with the ICC in April 2023, and the August 2022 United States Court of Appeals for the District of Columbia Circuit ruling that vacated FERC’s MISO ROE-determining orders and remanded the proceedings to the FERC;

•our ability to control costs and make substantial investments in our businesses, including our ability to recover costs and investments, and to earn our allowed ROEs, within frameworks established by our regulators, while maintaining affordability of our services for our customers;

•the effect of Ameren Illinois’ use of the performance-based formula ratemaking framework for its electric distribution service under the IEIMA, which established and allows for a reconciliation of electric distribution service rates through 2023, its participation in electric energy-efficiency programs, and the related impact of the direct relationship between Ameren Illinois’ ROE and the 30-year United States Treasury bond yields;

•the effect and duration of Ameren Illinois’ election to utilize MYRPs for electric distribution service ratemaking effective for rates beginning in 2024, including the effect of the reconciliation cap on the electric distribution revenue requirement;

•the effect on Ameren Missouri of any customer rate caps or limitations on increasing the electric service revenue requirement pursuant to Ameren Missouri’s election to use the PISA;

•Ameren Missouri’s ability to construct and/or acquire wind, solar, and other renewable energy generation facilities and battery storage, as well as natural gas-fired combined cycle energy centers, retire fossil fuel-fired energy centers, and implement new or existing customer energy-efficiency programs, including any such construction, acquisition, retirement, or implementation in connection with its Smart Energy Plan, integrated resource plan, or emissions reduction goals, and to recover its cost of investment, a related return, and, in the case of customer energy-efficiency programs, any lost margins in a timely manner, each of which is affected by the ability to obtain all necessary regulatory and project approvals, including CCNs from the MoPSC or any other required approvals for the addition of renewable resources;

•Ameren Missouri’s ability to use or transfer federal production and investment tax credits related to renewable energy projects; the cost of wind, solar, and other renewable generation and storage technologies; and our ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost for each facility;

•the success of competitive bids related to requests for proposals associated with the MISO’s long-range transmission planning;

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•the inability of our counterparties to meet their obligations with respect to contracts, credit agreements, and financial instruments, including as they relate to the construction and acquisition of electric and natural gas utility infrastructure and the ability of counterparties

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to complete projects, which is dependent upon the availability of necessary materials and equipment, including those obligations that are affected by supply chain disruptions;

•advancements in energy technologies, including carbon capture, utilization, and sequestration, hydrogen fuel for electric production and energy storage, next generation nuclear, ~~and~~ large-scale long-cycle battery energy storage, and the impact of federal and state energy and economic policies with respect to those technologies;

•the effects of changes in federal, state, or local laws and other governmental actions, including monetary, fiscal, foreign trade, and energy policies;

•the effects of changes in federal, state, or local tax laws or rates, including the effects of the IRA and the 15% minimum tax on adjusted financial statement income, as well as additional regulations, interpretations, amendments, or technical corrections to or in connection with the IRA, and challenges, if any, to the tax positions taken by the Ameren Companies, as well as resulting effects on customer rates and the recoverability of the minimum tax imposed under the IRA;

•the effects on energy prices and demand for our services resulting from technological advances, including advances in customer energy efficiency, electric vehicles, electrification of various industries, energy storage, and private generation sources, which generate electricity at the site of consumption and are becoming more cost-competitive;

•the cost and availability of fuel, such as low-sulfur coal, natural gas, and enriched uranium used to produce electricity; the cost and availability of natural gas for distribution and 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 from the one NRC-licensed supplier of Ameren Missouri’s Callaway Energy Center assemblies;

•the cost and availability of transmission capacity for the energy generated by Ameren Missouri’s energy centers or required to satisfy our energy sales;

•the effectiveness of our risk management strategies and our use of financial and derivative instruments;

•the ability to obtain sufficient insurance, or, in the absence of insurance, the ability to timely recover uninsured losses from our customers;

•the impact of cyberattacks and data security risks on us or our suppliers, which could, among other things, result in the loss of operational control of energy centers and electric and natural gas transmission and distribution systems and/or the loss of data, such as customer, employee, financial, and operating system information;

•acts of sabotage, which have increased in frequency and severity within the utility industry, war, terrorism, or other intentionally disruptive acts;

•business, economic, and capital market conditions, including the impact of such conditions on interest rates, inflation, and investments;

•the impact of inflation or a recession on our customers and the related impact on our results of operations, financial position, and liquidity;

•disruptions of the capital and credit markets, deterioration in credit metrics of the Ameren Companies, or other events that may have an adverse effect on the cost or availability of capital, including short-term credit and liquidity, and our ability to access the capital and credit markets on reasonable terms when needed;

•the actions of credit rating agencies and the effects of such actions;

•the impact of weather conditions and other natural phenomena on us and our customers, including the impact of system outages and the level of wind and solar resources;

•the construction, installation, performance, and cost recovery of generation, transmission, and distribution assets;

•the ability to maintain system reliability during the transition to clean energy generation by Ameren Missouri and the electric utility industry, including within the MISO, as well as Ameren Missouri’s ability to meet generation capacity obligations;

•the effects of failures of electric generation, electric and natural gas transmission or distribution, or natural gas storage facilities systems and equipment, which could result in unanticipated liabilities or unplanned outages;

•the operation of Ameren Missouri’s Callaway Energy Center, including planned and unplanned outages, as well as the ability to recover costs associated with such outages and the impact of such outages on off-system sales and purchased power, among other things;

•Ameren Missouri’s ability to recover the remaining investment and decommissioning costs associated with the retirement of an energy center, as well as the ability to earn a return on that remaining investment and those decommissioning costs;

•the impact of current environmental laws and new, more stringent, or changing requirements, including those related to NSR, CO2, NOx, and other emissions and discharges, Illinois emission standards, cooling water intake structures, CCR, energy efficiency, and wildlife protection, that could limit or terminate the operation of certain of Ameren Missouri’s energy centers, increase our operating costs or investment requirements, result in an impairment of our assets, cause us to sell our assets, reduce our customers’ demand for electricity or natural gas, or otherwise have a negative financial effect;

•the impact of complying with renewable energy standards in Missouri and Illinois and with the zero emission standard in Illinois;

•the effectiveness of Ameren Missouri’s customer energy-efficiency programs and the related revenues and performance incentives earned under its MEEIA programs;

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•Ameren Illinois’ ability to achieve the performance standards applicable to its electric distribution business and electric customer energy-efficiency goals and the resulting impact on its allowed ROE;

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•labor disputes, work force reductions, changes in future wage and employee benefits costs, including those resulting from changes in discount rates, mortality tables, returns on benefit plan assets, and other assumptions;

•the impact of negative opinions of us or our utility services that our customers, investors, legislators, regulators, creditors, or other stakeholders may have or develop, which could result from a variety of factors, including failures in system reliability, failure to implement our investment plans or to protect sensitive customer information, increases in rates, negative media coverage, or concerns about ESG practices;

•the impact of adopting new accounting guidance;

•the effects of strategic initiatives, including mergers, acquisitions, and divestitures;

•legal and administrative proceedings;

•pandemics or other health events, ~~including the COVID-19 pandemic,~~ and their impacts on our results of operations, financial position, and liquidity; and

•the impacts of the Russian invasion of Ukraine, related sanctions imposed by the U.S. and other governments, and any broadening of the conflict, including potential impacts on the cost and availability of fuel, natural gas, enriched uranium, and other commodities, materials, and services, the inability of our counterparties to perform their obligations, disruptions in the capital and credit markets, and other impacts on business, economic, and geopolitical conditions, including inflation.

New factors emerge from time to time, and it is not possible for us to predict all of such factors, nor can we 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 March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022
Operating Revenues:	Operating Revenues:							Operating Revenues:
Electric	Electric		$	1,590		$	1,318	Electric	$	1,585	$	1,513	$	3,175	$	2,831
Natural gas	Natural gas		472			561		Natural gas	175		213		647		774
Total operating revenues	Total operating revenues		2,062			1,879		Total operating revenues	1,760		1,726		3,822		3,605
Operating Expenses:	Operating Expenses:							Operating Expenses:
Fuel	Fuel		113			176		Fuel	152		83		265		259
Purchased power	Purchased power		495			177		Purchased power	328		318		823		495
Natural gas purchased for resale	Natural gas purchased for resale		208			293		Natural gas purchased for resale	42		80		250		373
Other operations and maintenance	Other operations and maintenance		448			461		Other operations and maintenance	450		491		898		952

Depreciation and amortization	Depreciation and amortization		320			299		Depreciation and amortization	335		316		655		615
Taxes other than income taxes	Taxes other than income taxes		127			142		Taxes other than income taxes	124		129		251		271
Total operating expenses	Total operating expenses		1,711			1,548		Total operating expenses	1,431		1,417		3,142		2,965
Operating Income	Operating Income		351			331		Operating Income	329		309		680		640

Other Income, Net	Other Income, Net		78			60		Other Income, Net	82		62		160		122
Interest Charges	Interest Charges		127			104		Interest Charges	134		126		261		230
Income Before Income Taxes	Income Before Income Taxes		302			287		Income Before Income Taxes	277		245		579		532
Income Taxes	Income Taxes		37			34		Income Taxes	38		36		75		70

Net Income	Net Income		265			253		Net Income	239		209		504		462
Less: Net Income Attributable to Noncontrolling Interests	Less: Net Income Attributable to Noncontrolling Interests		1			1		Less: Net Income Attributable to Noncontrolling Interests	2		2		3		3

Net Income Attributable to Ameren Common Shareholders	Net Income Attributable to Ameren Common Shareholders		$	264		$	252	Net Income Attributable to Ameren Common Shareholders	$	237	$	207	$	501	$	459

Net Income	Net Income		$	265		$	253	Net Income	$	239	$	209	$	504	$	462
Other Comprehensive Income (Loss), Net of Taxes	Other Comprehensive Income (Loss), Net of Taxes							Other Comprehensive Income (Loss), Net of Taxes
Pension and other postretirement benefit plan activity, net of income taxes of $— and $—, respectively			(1)			1
Pension and other postretirement benefit plan activity, net of income taxes of $—, $—, $—, and $—, respectively								Pension and other postretirement benefit plan activity, net of income taxes of $—, $—, $—, and $—, respectively	(1)		—		(2)		1
Comprehensive Income	Comprehensive Income		264			254		Comprehensive Income	238		209		502		463
Less: Comprehensive Income Attributable to Noncontrolling Interests	Less: Comprehensive Income Attributable to Noncontrolling Interests		1			1		Less: Comprehensive Income Attributable to Noncontrolling Interests	2		2		3		3
Comprehensive Income Attributable to Ameren Common Shareholders	Comprehensive Income Attributable to Ameren Common Shareholders		$	263		$	253	Comprehensive Income Attributable to Ameren Common Shareholders	$	236	$	207	$	499	$	460

Earnings per Common Share – Basic	Earnings per Common Share – Basic		$	1.01		$	0.98	Earnings per Common Share – Basic	$	0.90	$	0.80	$	1.91	$	1.78

Earnings per Common Share – Diluted	Earnings per Common Share – Diluted		$	1.00		$	0.97	Earnings per Common Share – Diluted	$	0.90	$	0.80	$	1.90	$	1.77

Weighted-average Common Shares Outstanding – Basic	Weighted-average Common Shares Outstanding – Basic		262.2			257.9		Weighted-average Common Shares Outstanding – Basic	262.6		258.2		262.4		258.0
Weighted-average Common Shares Outstanding – Diluted	Weighted-average Common Shares Outstanding – Diluted		263.1			259.0		Weighted-average Common Shares Outstanding – Diluted	263.2		259.4		263.2		259.2

The accompanying notes are an integral part of these consolidated financial statements.

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AMEREN CORPORATION

CONSOLIDATED BALANCE SHEET

(Unaudited) (In millions, except per share amounts)


		March 31, 2023		December 31, 2022			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	10	$	10	Cash and cash equivalents	$	7	$	10
Accounts receivable – trade (less allowance for doubtful accounts of $34 and $31, respectively)		625		600
Accounts receivable – trade (less allowance for doubtful accounts of $39 and $31, respectively)						Accounts receivable – trade (less allowance for doubtful accounts of $39 and $31, respectively)	482		600
Unbilled revenue	Unbilled revenue	299		446		Unbilled revenue	378		446
Miscellaneous accounts receivable	Miscellaneous accounts receivable	62		54		Miscellaneous accounts receivable	63		54
Inventories	Inventories	630		667		Inventories	711		667

Current regulatory assets	Current regulatory assets	292		354		Current regulatory assets	239		354

Investment in industrial development revenue bonds	Investment in industrial development revenue bonds	—		240		Investment in industrial development revenue bonds	—		240
Current collateral assets	Current collateral assets	29		142		Current collateral assets	20		142
Other current assets	Other current assets	115		155		Other current assets	119		155

Total current assets	Total current assets	2,062		2,668		Total current assets	2,019		2,668
Property, Plant, and Equipment, Net	Property, Plant, and Equipment, Net	31,735		31,262		Property, Plant, and Equipment, Net	32,351		31,262
Investments and Other Assets:	Investments and Other Assets:					Investments and Other Assets:
Nuclear decommissioning trust fund	Nuclear decommissioning trust fund	1,019		958		Nuclear decommissioning trust fund	1,075		958
Goodwill	Goodwill	411		411		Goodwill	411		411

Regulatory assets	Regulatory assets	1,599		1,426		Regulatory assets	1,790		1,426
Pension and other postretirement benefits	Pension and other postretirement benefits	423		411		Pension and other postretirement benefits	442		411
Other assets	Other assets	815		768		Other assets	859		768

Total investments and other assets	Total investments and other assets	4,267		3,974		Total investments and other assets	4,577		3,974
TOTAL ASSETS	TOTAL ASSETS	$	38,064	$	37,904	TOTAL ASSETS	$	38,947	$	37,904
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:
Current maturities of long-term debt	Current maturities of long-term debt	$	100	$	340	Current maturities of long-term debt	$	350	$	340
Short-term debt	Short-term debt	1,248		1,070		Short-term debt	1,329		1,070
Accounts and wages payable	Accounts and wages payable	664		1,159		Accounts and wages payable	719		1,159

Other current liabilities	Other current liabilities	745		797		Other current liabilities	845		797

Total current liabilities	Total current liabilities	2,757		3,366		Total current liabilities	3,243		3,366
Long-term Debt, Net	Long-term Debt, Net	14,181		13,685		Long-term Debt, Net	14,328		13,685
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and tax credits, net	Accumulated deferred income taxes and tax credits, net	3,856		3,804		Accumulated deferred income taxes and tax credits, net	3,913		3,804

Regulatory liabilities	Regulatory liabilities	5,395		5,309		Regulatory liabilities	5,445		5,309
Asset retirement obligations	Asset retirement obligations	769		763		Asset retirement obligations	775		763

Other deferred credits and liabilities	Other deferred credits and liabilities	370		340		Other deferred credits and liabilities	417		340

Total deferred credits and other liabilities	Total deferred credits and other liabilities	10,390		10,216		Total deferred credits and other liabilities	10,550		10,216
Commitments and Contingencies (Notes 2, 9, and 10)	Commitments and Contingencies (Notes 2, 9, and 10)					Commitments and Contingencies (Notes 2, 9, and 10)
Shareholders’ Equity:	Shareholders’ Equity:					Shareholders’ Equity:
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 262.6 and 262.0, respectively		3		3
Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 262.7 and 262.0, respectively						Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 262.7 and 262.0, respectively	3		3
Other paid-in capital, principally premium on common stock	Other paid-in capital, principally premium on common stock	6,861		6,860		Other paid-in capital, principally premium on common stock	6,880		6,860
Retained earnings	Retained earnings	3,745		3,646		Retained earnings	3,817		3,646
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(2)		(1)		Accumulated other comprehensive loss	(3)		(1)

Total shareholders’ equity	Total shareholders’ equity	10,607		10,508		Total shareholders’ equity	10,697		10,508
Noncontrolling Interests	Noncontrolling Interests	129		129		Noncontrolling Interests	129		129
Total equity	Total equity	10,736		10,637		Total equity	10,826		10,637
TOTAL LIABILITIES AND EQUITY	TOTAL LIABILITIES AND EQUITY	$	38,064	$	37,904	TOTAL LIABILITIES AND EQUITY	$	38,947	$	37,904

The accompanying notes are an integral part of these consolidated financial statements.

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AMEREN CORPORATION	AMEREN CORPORATION					AMEREN CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS	CONSOLIDATED STATEMENT OF CASH FLOWS					CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited) (In millions)	(Unaudited) (In millions)					(Unaudited) (In millions)
		Three Months Ended March 31,					Six Months Ended June 30,
		2023		2022			2023		2022
Cash Flows From Operating Activities:	Cash Flows From Operating Activities:					Cash Flows From Operating Activities:
Net income	Net income	$	265	$	253	Net income	$	504	$	462

Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization	Depreciation and amortization	350		324		Depreciation and amortization	703		665
Amortization of nuclear fuel	Amortization of nuclear fuel	19		22		Amortization of nuclear fuel	36		28
Amortization of debt issuance costs and premium/discounts	Amortization of debt issuance costs and premium/discounts	3		4		Amortization of debt issuance costs and premium/discounts	8		12
Deferred income taxes and investment tax credits, net	Deferred income taxes and investment tax credits, net	35		31		Deferred income taxes and investment tax credits, net	66		66
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(9)		(8)		Allowance for equity funds used during construction	(23)		(19)
Stock-based compensation costs	Stock-based compensation costs	8		4		Stock-based compensation costs	14		12
Other	Other	(6)		11		Other	(19)		33
Changes in assets and liabilities:	Changes in assets and liabilities:					Changes in assets and liabilities:
Receivables	Receivables	112		(117)		Receivables	173		(187)
Inventories	Inventories	37		72		Inventories	(44)		(8)
Accounts and wages payable	Accounts and wages payable	(362)		(235)		Accounts and wages payable	(335)		(87)
Taxes accrued	Taxes accrued	50		47		Taxes accrued	93		94
Regulatory assets and liabilities	Regulatory assets and liabilities	(40)		75		Regulatory assets and liabilities	(81)		(74)
Assets, other	Assets, other	(14)		(10)		Assets, other	(38)		(35)
Liabilities, other	Liabilities, other	(6)		(39)		Liabilities, other	34		45
Pension and other postretirement benefits	Pension and other postretirement benefits	(58)		(15)		Pension and other postretirement benefits	(114)		(32)
Counterparty collateral, net	Counterparty collateral, net	112		(31)		Counterparty collateral, net	134		(103)

Net cash provided by operating activities	Net cash provided by operating activities	496		388		Net cash provided by operating activities	1,111		872
Cash Flows From Investing Activities:	Cash Flows From Investing Activities:					Cash Flows From Investing Activities:
Capital expenditures	Capital expenditures	(931)		(774)		Capital expenditures	(1,822)		(1,538)

Nuclear fuel expenditures	Nuclear fuel expenditures	(20)		(16)		Nuclear fuel expenditures	(50)		(22)
Purchases of securities – nuclear decommissioning trust fund	Purchases of securities – nuclear decommissioning trust fund	(29)		(97)		Purchases of securities – nuclear decommissioning trust fund	(81)		(122)
Sales and maturities of securities – nuclear decommissioning trust fund	Sales and maturities of securities – nuclear decommissioning trust fund	17		92		Sales and maturities of securities – nuclear decommissioning trust fund	65		114

Other	Other	(1)		15		Other	(1)		16

Net cash used in investing activities	Net cash used in investing activities	(964)		(780)		Net cash used in investing activities	(1,889)		(1,552)
Cash Flows From Financing Activities:	Cash Flows From Financing Activities:					Cash Flows From Financing Activities:
Dividends on common stock	Dividends on common stock	(165)		(152)		Dividends on common stock	(330)		(305)
Dividends paid to noncontrolling interest holders	Dividends paid to noncontrolling interest holders	(1)		(1)		Dividends paid to noncontrolling interest holders	(3)		(3)
Short-term debt, net	Short-term debt, net	179		555		Short-term debt, net	260		475

Maturities of long-term debt						Maturities of long-term debt	(100)		—

Issuances of long-term debt	Issuances of long-term debt	499		—		Issuances of long-term debt	997		524
Issuances of common stock	Issuances of common stock	5		5		Issuances of common stock	16		17

Employee payroll taxes related to stock-based compensation	Employee payroll taxes related to stock-based compensation	(20)		(16)		Employee payroll taxes related to stock-based compensation	(20)		(16)
Debt issuance costs	Debt issuance costs	(5)		—		Debt issuance costs	(9)		(6)
Other	Other	(3)		—		Other	(3)		—

Net cash provided by financing activities	Net cash provided by financing activities	489		391		Net cash provided by financing activities	808		686
Net change in cash, cash equivalents, and restricted cash	Net change in cash, cash equivalents, and restricted cash	21		(1)		Net change in cash, cash equivalents, and restricted cash	30		6
Cash, cash equivalents, and restricted cash at beginning of year	Cash, cash equivalents, and restricted cash at beginning of year	216		155		Cash, cash equivalents, and restricted cash at beginning of year	216		155

Cash, cash equivalents, and restricted cash at end of period	Cash, cash equivalents, and restricted cash at end of period	$	237	$	154	Cash, cash equivalents, and restricted cash at end of period	$	246	$	161

The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

AMEREN CORPORATION

CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY

(Unaudited) (In millions, except per share amounts)


		Three Months Ended March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022

Common Stock	Common Stock		$	3		$	3	Common Stock	$	3	$	3	$	3	$	3

Other Paid-in Capital:	Other Paid-in Capital:							Other Paid-in Capital:
Beginning of year			6,860			6,502
Beginning of period								Beginning of period	6,861		6,507		6,860		6,502

Shares issued under the DRPlus and 401(k) plan	Shares issued under the DRPlus and 401(k) plan		12			13		Shares issued under the DRPlus and 401(k) plan	11		12		23		25
Stock-based compensation activity	Stock-based compensation activity		(11)			(8)		Stock-based compensation activity	8		8		(3)		—

Other paid-in capital, end of period	Other paid-in capital, end of period		6,861			6,507		Other paid-in capital, end of period	6,880		6,527		6,880		6,527

Retained Earnings:	Retained Earnings:							Retained Earnings:
Beginning of year			3,646			3,182
Beginning of period								Beginning of period	3,745		3,282		3,646		3,182
Net income attributable to Ameren common shareholders	Net income attributable to Ameren common shareholders		264			252		Net income attributable to Ameren common shareholders	237		207		501		459
Dividends on common stock	Dividends on common stock		(165)			(152)		Dividends on common stock	(165)		(153)		(330)		(305)

Retained earnings, end of period	Retained earnings, end of period		3,745			3,282		Retained earnings, end of period	3,817		3,336		3,817		3,336

Accumulated Other Comprehensive Income (Loss):	Accumulated Other Comprehensive Income (Loss):							Accumulated Other Comprehensive Income (Loss):

Deferred retirement benefit costs, beginning of year			(1)			13
Deferred retirement benefit costs, beginning of period								Deferred retirement benefit costs, beginning of period	(2)		14		(1)		13

Change in deferred retirement benefit costs	Change in deferred retirement benefit costs		(1)			1		Change in deferred retirement benefit costs	(1)		—		(2)		1

Deferred retirement benefit costs, end of period	Deferred retirement benefit costs, end of period		(2)			14		Deferred retirement benefit costs, end of period	(3)		14		(3)		14
Total accumulated other comprehensive income (loss), end of period	Total accumulated other comprehensive income (loss), end of period		(2)			14		Total accumulated other comprehensive income (loss), end of period	(3)		14		(3)		14
Total Shareholders’ Equity	Total Shareholders’ Equity		$	10,607		$	9,806	Total Shareholders’ Equity	$	10,697	$	9,880	$	10,697	$	9,880

Noncontrolling Interests:	Noncontrolling Interests:							Noncontrolling Interests:
Beginning of year			129			129
Beginning of period								Beginning of period	129		129		129		129
Net income attributable to noncontrolling interest holders	Net income attributable to noncontrolling interest holders		1			1		Net income attributable to noncontrolling interest holders	2		2		3		3
Dividends paid to noncontrolling interest holders	Dividends paid to noncontrolling interest holders		(1)			(1)		Dividends paid to noncontrolling interest holders	(2)		(2)		(3)		(3)

Noncontrolling interests, end of period	Noncontrolling interests, end of period		129			129		Noncontrolling interests, end of period	129		129		129		129
Total Equity	Total Equity		$	10,736		$	9,935	Total Equity	$	10,826	$	10,009	$	10,826	$	10,009

Common stock shares outstanding at beginning of year			262.0			257.7
Common stock shares outstanding at beginning of period								Common stock shares outstanding at beginning of period	262.6		258.2		262.0		257.7

Shares issued under the DRPlus and 401(k) plan	Shares issued under the DRPlus and 401(k) plan		0.1			0.1		Shares issued under the DRPlus and 401(k) plan	0.1		0.2		0.2		0.3
Shares issued for stock-based compensation	Shares issued for stock-based compensation		0.5			0.4		Shares issued for stock-based compensation	—		—		0.5		0.4
Common stock shares outstanding at end of period	Common stock shares outstanding at end of period		262.6			258.2		Common stock shares outstanding at end of period	262.7		258.4		262.7		258.4

Dividends per common share	Dividends per common share		$	0.63		$	0.59	Dividends per common share	$	0.63	$	0.59	$	1.26	$	1.18

The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)

CONSOLIDATED STATEMENT OF INCOME

(Unaudited) (In millions)


		Three Months Ended March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022
Operating Revenues:	Operating Revenues:							Operating Revenues:
Electric	Electric		$	841		$	738	Electric	$	918	$	890	$	1,759	$	1,628
Natural gas	Natural gas		82			80		Natural gas	23		29		105		109

Total operating revenues	Total operating revenues		923			818		Total operating revenues	941		919		1,864		1,737
Operating Expenses:	Operating Expenses:							Operating Expenses:
Fuel	Fuel		113			176		Fuel	152		83		265		259
Purchased power	Purchased power		208			50		Purchased power	137		161		345		211
Natural gas purchased for resale	Natural gas purchased for resale		47			46		Natural gas purchased for resale	9		12		56		58
Other operations and maintenance	Other operations and maintenance		239			232		Other operations and maintenance	237		260		476		492

Depreciation and amortization	Depreciation and amortization		176			164		Depreciation and amortization	186		178		362		342
Taxes other than income taxes	Taxes other than income taxes		80			85		Taxes other than income taxes	88		90		168		175
Total operating expenses	Total operating expenses		863			753		Total operating expenses	809		784		1,672		1,537
Operating Income	Operating Income		60			65		Operating Income	132		135		192		200

Other Income, Net	Other Income, Net		19			23		Other Income, Net	22		24		41		47
Interest Charges	Interest Charges		51			39		Interest Charges	52		60		103		99
Income Before Income Taxes	Income Before Income Taxes		28			49		Income Before Income Taxes	102		99		130		148
Income Taxes Benefit	Income Taxes Benefit		(1)			(2)		Income Taxes Benefit	(1)		(2)		(2)		(4)
Net Income	Net Income		29			51		Net Income	103		101		132		152

Preferred Stock Dividends	Preferred Stock Dividends		1			1		Preferred Stock Dividends	1		1		2		2
Net Income Available to Common Shareholder	Net Income Available to Common Shareholder		$	28		$	50	Net Income Available to Common Shareholder	$	102	$	100	$	130	$	150

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.

Table of Contents

UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)

CONSOLIDATED BALANCE SHEET

(Unaudited) (In millions, except per share amounts)


		March 31, 2023		December 31, 2022			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	3	$	—	Cash and cash equivalents	$	—	$	—

Accounts receivable – trade (less allowance for doubtful accounts of $12 and $13, respectively)	Accounts receivable – trade (less allowance for doubtful accounts of $12 and $13, respectively)	205		244		Accounts receivable – trade (less allowance for doubtful accounts of $12 and $13, respectively)	185		244
Accounts receivable – affiliates	Accounts receivable – affiliates	70		51		Accounts receivable – affiliates	49		51
Unbilled revenue	Unbilled revenue	148		184		Unbilled revenue	248		184
Miscellaneous accounts receivable	Miscellaneous accounts receivable	18		18		Miscellaneous accounts receivable	19		18
Inventories	Inventories	475		434		Inventories	515		434

Current regulatory assets	Current regulatory assets	194		254		Current regulatory assets	144		254
Investment in industrial development revenue bonds	Investment in industrial development revenue bonds	—		240		Investment in industrial development revenue bonds	—		240
Current collateral assets	Current collateral assets	29		101		Current collateral assets	20		101
Other current assets	Other current assets	40		66		Other current assets	44		66
Total current assets	Total current assets	1,182		1,592		Total current assets	1,224		1,592
Property, Plant, and Equipment, Net	Property, Plant, and Equipment, Net	16,326		16,124		Property, Plant, and Equipment, Net	16,560		16,124
Investments and Other Assets:	Investments and Other Assets:					Investments and Other Assets:
Nuclear decommissioning trust fund	Nuclear decommissioning trust fund	1,019		958		Nuclear decommissioning trust fund	1,075		958

Regulatory assets	Regulatory assets	628		594		Regulatory assets	676		594
Pension and other postretirement benefits	Pension and other postretirement benefits	102		98		Pension and other postretirement benefits	111		98
Other assets	Other assets	136		140		Other assets	138		140
Total investments and other assets	Total investments and other assets	1,885		1,790		Total investments and other assets	2,000		1,790
TOTAL ASSETS	TOTAL ASSETS	$	19,393	$	19,506	TOTAL ASSETS	$	19,784	$	19,506
LIABILITIES AND SHAREHOLDERS’ EQUITY	LIABILITIES AND SHAREHOLDERS’ EQUITY					LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:
Current maturities of long-term debt	Current maturities of long-term debt	$	—	$	240	Current maturities of long-term debt	$	350	$	240
Short-term debt	Short-term debt	197		329		Short-term debt	373		329

Accounts and wages payable	Accounts and wages payable	294		606		Accounts and wages payable	275		606
Accounts payable – affiliates	Accounts payable – affiliates	36		43		Accounts payable – affiliates	40		43
Taxes accrued	Taxes accrued	76		29		Taxes accrued	127		29
Interest accrued		50		63

Other current liabilities	Other current liabilities	187		260		Other current liabilities	253		323
Total current liabilities	Total current liabilities	840		1,570		Total current liabilities	1,418		1,570
Long-term Debt, Net	Long-term Debt, Net	6,341		5,846		Long-term Debt, Net	5,991		5,846
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and tax credits, net	Accumulated deferred income taxes and tax credits, net	2,003		1,982		Accumulated deferred income taxes and tax credits, net	2,015		1,982

Regulatory liabilities	Regulatory liabilities	2,934		2,871		Regulatory liabilities	2,972		2,871
Asset retirement obligations	Asset retirement obligations	765		759		Asset retirement obligations	771		759

Other deferred credits and liabilities	Other deferred credits and liabilities	55		51		Other deferred credits and liabilities	60		51
Total deferred credits and other liabilities	Total deferred credits and other liabilities	5,757		5,663		Total deferred credits and other liabilities	5,818		5,663
Commitments and Contingencies (Notes 2, 8, 9, and 10)	Commitments and Contingencies (Notes 2, 8, 9, and 10)					Commitments and Contingencies (Notes 2, 8, 9, and 10)
Shareholders’ Equity:	Shareholders’ Equity:					Shareholders’ Equity:
Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding	Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding	511		511		Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding	511		511
Other paid-in capital, principally premium on common stock	Other paid-in capital, principally premium on common stock	2,725		2,725		Other paid-in capital, principally premium on common stock	2,725		2,725
Preferred stock	Preferred stock	80		80		Preferred stock	80		80
Retained earnings	Retained earnings	3,139		3,111		Retained earnings	3,241		3,111
Total shareholders’ equity	Total shareholders’ equity	6,455		6,427		Total shareholders’ equity	6,557		6,427
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	19,393	$	19,506	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	19,784	$	19,506

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.

Table of Contents

UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)

CONSOLIDATED STATEMENT OF CASH FLOWS

(Unaudited) (In millions)


		Three Months Ended March 31,					Six Months Ended June 30,
		2023		2022			2023		2022
Cash Flows From Operating Activities:	Cash Flows From Operating Activities:					Cash Flows From Operating Activities:
Net income	Net income	$	29	$	51	Net income	$	132	$	152
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization	Depreciation and amortization	205		189		Depreciation and amortization	410		393
Amortization of nuclear fuel	Amortization of nuclear fuel	19		22		Amortization of nuclear fuel	36		28

Amortization of debt issuance costs and premium/discounts	Amortization of debt issuance costs and premium/discounts	2		1		Amortization of debt issuance costs and premium/discounts	3		3
Deferred income taxes and investment tax credits, net	Deferred income taxes and investment tax credits, net	15		4		Deferred income taxes and investment tax credits, net	10		19
Allowance for equity funds used during construction	Allowance for equity funds used during construction	(4)		(4)		Allowance for equity funds used during construction	(12)		(10)
Other	Other	(3)		—		Other	(20)		4
Changes in assets and liabilities:	Changes in assets and liabilities:					Changes in assets and liabilities:
Receivables	Receivables	74		7		Receivables	(9)		(105)
Inventories	Inventories	(41)		5		Inventories	(81)		(7)
Accounts and wages payable	Accounts and wages payable	(238)		(201)		Accounts and wages payable	(231)		(159)
Taxes accrued	Taxes accrued	38		41		Taxes accrued	103		81
Regulatory assets and liabilities	Regulatory assets and liabilities	14		(3)		Regulatory assets and liabilities	28		(128)
Assets, other	Assets, other	2		10		Assets, other	13		12
Liabilities, other	Liabilities, other	(11)		(23)		Liabilities, other	21		24
Pension and other postretirement benefits	Pension and other postretirement benefits	(21)		(4)		Pension and other postretirement benefits	(41)		(8)
Counterparty collateral, net	Counterparty collateral, net	73		(39)		Counterparty collateral, net	81		(118)
Net cash provided by operating activities	Net cash provided by operating activities	153		56		Net cash provided by operating activities	443		181
Cash Flows From Investing Activities:	Cash Flows From Investing Activities:					Cash Flows From Investing Activities:
Capital expenditures	Capital expenditures	(481)		(414)		Capital expenditures	(914)		(806)

Nuclear fuel expenditures	Nuclear fuel expenditures	(20)		(16)		Nuclear fuel expenditures	(50)		(22)
Purchases of securities – nuclear decommissioning trust fund	Purchases of securities – nuclear decommissioning trust fund	(29)		(97)		Purchases of securities – nuclear decommissioning trust fund	(81)		(122)
Sales and maturities of securities – nuclear decommissioning trust fund	Sales and maturities of securities – nuclear decommissioning trust fund	17		92		Sales and maturities of securities – nuclear decommissioning trust fund	65		114

Other	Other	—		18		Other	—		18
Net cash used in investing activities	Net cash used in investing activities	(513)		(417)		Net cash used in investing activities	(980)		(818)
Cash Flows From Financing Activities:	Cash Flows From Financing Activities:					Cash Flows From Financing Activities:

Dividends on preferred stock	Dividends on preferred stock	(1)		(1)		Dividends on preferred stock	(2)		(2)
Short-term debt, net	Short-term debt, net	(132)		363		Short-term debt, net	44		120

Issuances of long-term debt	Issuances of long-term debt	499		—		Issuances of long-term debt	499		524

Debt issuance costs	Debt issuance costs	(5)		—		Debt issuance costs	(6)		(6)
Other	Other	(3)		—		Other	(3)		—
Net cash provided by financing activities	Net cash provided by financing activities	358		362		Net cash provided by financing activities	532		636
Net change in cash, cash equivalents, and restricted cash	Net change in cash, cash equivalents, and restricted cash	(2)		1		Net change in cash, cash equivalents, and restricted cash	(5)		(1)
Cash, cash equivalents, and restricted cash at beginning of year	Cash, cash equivalents, and restricted cash at beginning of year	13		8		Cash, cash equivalents, and restricted cash at beginning of year	13		8
Cash, cash equivalents, and restricted cash at end of period	Cash, cash equivalents, and restricted cash at end of period	$	11	$	9	Cash, cash equivalents, and restricted cash at end of period	$	8	$	7

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.

Table of Contents

UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI)

CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY

(Unaudited) (In millions)


		Three Months Ended March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022
Common Stock	Common Stock		$	511		$	511	Common Stock	$	511	$	511	$	511	$	511

Other Paid-in Capital	Other Paid-in Capital		2,725			2,725		Other Paid-in Capital	2,725		2,725		2,725		2,725

Preferred Stock	Preferred Stock		80			80		Preferred Stock	80		80		80		80

Retained Earnings:	Retained Earnings:							Retained Earnings:
Beginning of year			3,111			2,595
Beginning of period								Beginning of period	3,139		2,645		3,111		2,595
Net income	Net income		29			51		Net income	103		101		132		152

Dividends on preferred stock	Dividends on preferred stock		(1)			(1)		Dividends on preferred stock	(1)		(1)		(2)		(2)
Retained earnings, end of period	Retained earnings, end of period		3,139			2,645		Retained earnings, end of period	3,241		2,745		3,241		2,745

Total Shareholders’ Equity	Total Shareholders’ Equity		$	6,455		$	5,961	Total Shareholders’ Equity	$	6,557	$	6,061	$	6,557	$	6,061

The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.

Table of Contents

AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS)

STATEMENT OF INCOME

(Unaudited) (In millions)


		Three Months Ended March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022
Operating Revenues:	Operating Revenues:							Operating Revenues:
Electric	Electric		$	710		$	543	Electric	$	627	$	585	$	1,337	$	1,128
Natural gas	Natural gas		391			481		Natural gas	152		184		543		665
Total operating revenues	Total operating revenues		1,101			1,024		Total operating revenues	779		769		1,880		1,793
Operating Expenses:	Operating Expenses:							Operating Expenses:
Purchased power	Purchased power		287			131		Purchased power	192		158		479		289
Natural gas purchased for resale	Natural gas purchased for resale		161			247		Natural gas purchased for resale	33		68		194		315
Other operations and maintenance	Other operations and maintenance		202			223		Other operations and maintenance	201		225		403		448
Depreciation and amortization	Depreciation and amortization		133			124		Depreciation and amortization	138		128		271		252
Taxes other than income taxes	Taxes other than income taxes		42			53		Taxes other than income taxes	32		35		74		88
Total operating expenses	Total operating expenses		825			778		Total operating expenses	596		614		1,421		1,392
Operating Income	Operating Income		276			246		Operating Income	183		155		459		401

Other Income, Net	Other Income, Net		37			24		Other Income, Net	41		25		78		49
Interest Charges	Interest Charges		47			42		Interest Charges	50		41		97		83
Income Before Income Taxes	Income Before Income Taxes		266			228		Income Before Income Taxes	174		139		440		367
Income Taxes	Income Taxes		68			59		Income Taxes	44		35		112		94
Net Income								Net Income	130		104		328		273

Preferred Stock Dividends								Preferred Stock Dividends	1		1		1		1
Net Income Available to Common Shareholder	Net Income Available to Common Shareholder		$	198		$	169	Net Income Available to Common Shareholder	$	129	$	103	$	327	$	272

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)


		March 31, 2023		December 31, 2022			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	Cash and cash equivalents	$	—	$	—

Accounts receivable – trade (less allowance for doubtful accounts of $22 and $18, respectively)		406		341
Accounts receivable – trade (less allowance for doubtful accounts of $27 and $18, respectively)						Accounts receivable – trade (less allowance for doubtful accounts of $27 and $18, respectively)	281		341
Accounts receivable – affiliates	Accounts receivable – affiliates	14		12		Accounts receivable – affiliates	10		12
Unbilled revenue	Unbilled revenue	151		262		Unbilled revenue	130		262
Miscellaneous accounts receivable	Miscellaneous accounts receivable	32		23		Miscellaneous accounts receivable	29		23
Inventories	Inventories	155		233		Inventories	196		233

Current regulatory assets	Current regulatory assets	89		87		Current regulatory assets	88		87

Other current assets	Other current assets	36		98		Other current assets	36		98
Total current assets	Total current assets	883		1,056		Total current assets	770		1,056
Property, Plant, and Equipment, Net	Property, Plant, and Equipment, Net	13,602		13,353		Property, Plant, and Equipment, Net	13,955		13,353
Investments and Other Assets:	Investments and Other Assets:					Investments and Other Assets:
Goodwill	Goodwill	411		411		Goodwill	411		411
Regulatory assets	Regulatory assets	954		821		Regulatory assets	1,091		821
Pension and other postretirement benefits	Pension and other postretirement benefits	324		318		Pension and other postretirement benefits	335		318
Other assets	Other assets	510		482		Other assets	548		482
Total investments and other assets	Total investments and other assets	2,199		2,032		Total investments and other assets	2,385		2,032
TOTAL ASSETS	TOTAL ASSETS	$	16,684	$	16,441	TOTAL ASSETS	$	17,110	$	16,441
LIABILITIES AND SHAREHOLDERS’ EQUITY	LIABILITIES AND SHAREHOLDERS’ EQUITY					LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:	Current Liabilities:					Current Liabilities:
Current maturities of long-term debt	Current maturities of long-term debt	$	100	$	100	Current maturities of long-term debt	$	—	$	100
Short-term debt	Short-term debt	324		264		Short-term debt	117		264

Accounts and wages payable	Accounts and wages payable	304		451		Accounts and wages payable	357		451
Accounts payable – affiliates	Accounts payable – affiliates	117		93		Accounts payable – affiliates	68		93

Customer deposits						Customer deposits	111		87

Current regulatory liabilities						Current regulatory liabilities	82		64
Other current liabilities	Other current liabilities	398		383		Other current liabilities	212		232
Total current liabilities	Total current liabilities	1,243		1,291		Total current liabilities	947		1,291
Long-term Debt, Net	Long-term Debt, Net	4,736		4,735		Long-term Debt, Net	5,232		4,735
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and investment tax credits, net	Accumulated deferred income taxes and investment tax credits, net	1,744		1,699		Accumulated deferred income taxes and investment tax credits, net	1,783		1,699

Regulatory liabilities	Regulatory liabilities	2,334		2,313		Regulatory liabilities	2,344		2,313

Other deferred credits and liabilities	Other deferred credits and liabilities	261		235		Other deferred credits and liabilities	309		235
Total deferred credits and other liabilities	Total deferred credits and other liabilities	4,339		4,247		Total deferred credits and other liabilities	4,436		4,247
Commitments and Contingencies (Notes 2, 8, and 9)	Commitments and Contingencies (Notes 2, 8, and 9)					Commitments and Contingencies (Notes 2, 8, and 9)
Shareholders’ Equity:	Shareholders’ Equity:					Shareholders’ Equity:
Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding	Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding	—		—		Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding	—		—
Other paid-in capital	Other paid-in capital	2,929		2,929		Other paid-in capital	2,929		2,929
Preferred stock	Preferred stock	49		49		Preferred stock	49		49
Retained earnings	Retained earnings	3,388		3,190		Retained earnings	3,517		3,190

Total shareholders’ equity	Total shareholders’ equity	6,366		6,168		Total shareholders’ equity	6,495		6,168
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	16,684	$	16,441	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	17,110	$	16,441

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)


		Three Months Ended March 31,					Six Months Ended June 30,
		2023		2022			2023		2022
Cash Flows From Operating Activities:	Cash Flows From Operating Activities:					Cash Flows From Operating Activities:
Net income	Net income	$	198	$	169	Net income	$	328	$	273
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	133		124		Depreciation and amortization	271		251
Amortization of debt issuance costs and premium/discounts	Amortization of debt issuance costs and premium/discounts	1		3		Amortization of debt issuance costs and premium/discounts	2		6
Deferred income taxes and investment tax credits, net	Deferred income taxes and investment tax credits, net	37		27		Deferred income taxes and investment tax credits, net	70		55

Allowance for equity funds used during construction	Allowance for equity funds used during construction	(4)		(4)		Allowance for equity funds used during construction	(10)		(9)
Other	Other	6		2		Other	12		6
Changes in assets and liabilities:	Changes in assets and liabilities:					Changes in assets and liabilities:
Receivables	Receivables	26		(126)		Receivables	182		(76)
Inventories	Inventories	78		67		Inventories	37		(1)
Accounts and wages payable	Accounts and wages payable	(112)		(18)		Accounts and wages payable	(92)		76
Taxes accrued	Taxes accrued	25		32		Taxes accrued	(36)		62
Regulatory assets and liabilities	Regulatory assets and liabilities	(52)		79		Regulatory assets and liabilities	(105)		55
Assets, other	Assets, other	(8)		(18)		Assets, other	(42)		(43)
Liabilities, other	Liabilities, other	30		5		Liabilities, other	13		23
Pension and other postretirement benefits	Pension and other postretirement benefits	(24)		(8)		Pension and other postretirement benefits	(46)		(18)
Counterparty collateral, net	Counterparty collateral, net	39		8		Counterparty collateral, net	53		15

Net cash provided by operating activities	Net cash provided by operating activities	373		342		Net cash provided by operating activities	637		675
Cash Flows From Investing Activities:	Cash Flows From Investing Activities:					Cash Flows From Investing Activities:
Capital expenditures	Capital expenditures	(407)		(342)		Capital expenditures	(844)		(699)

Other						Other	(2)		—
Net cash used in investing activities	Net cash used in investing activities	(407)		(342)		Net cash used in investing activities	(846)		(699)
Cash Flows From Financing Activities:	Cash Flows From Financing Activities:					Cash Flows From Financing Activities:

Dividends on preferred stock						Dividends on preferred stock	(1)		(1)
Short-term debt, net						Short-term debt, net	(147)		38

Short-term debt, net		60		4
Maturities of long-term debt						Maturities of long-term debt	(100)		—
Issuances of long-term debt						Issuances of long-term debt	498		—

Debt issuance costs						Debt issuance costs	(3)		—

Net cash provided by financing activities	Net cash provided by financing activities	60		4		Net cash provided by financing activities	247		37
Net change in cash, cash equivalents, and restricted cash	Net change in cash, cash equivalents, and restricted cash	26		4		Net change in cash, cash equivalents, and restricted cash	38		13
Cash, cash equivalents and restricted cash at beginning of year	Cash, cash equivalents and restricted cash at beginning of year	191		133		Cash, cash equivalents and restricted cash at beginning of year	191		133
Cash, cash equivalents, and restricted cash at end of period	Cash, cash equivalents, and restricted cash at end of period	$	217	$	137	Cash, cash equivalents, and restricted cash at end of period	$	229	$	146

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 March 31,			Three Months Ended June 30,						Six Months Ended June 30,
			2023			2022			2023		2022		2023		2022
Common Stock	Common Stock		$	—		$	—	Common Stock	$	—	$	—	$	—	$	—

Other Paid-in Capital	Other Paid-in Capital		2,929			2,914		Other Paid-in Capital	2,929		2,914		2,929		2,914

Preferred Stock	Preferred Stock		49			49		Preferred Stock	49		49		49		49

Retained Earnings:	Retained Earnings:							Retained Earnings:
Beginning of year			3,190			2,677
Beginning of period								Beginning of period	3,388		2,846		3,190		2,677
Net income	Net income		198			169		Net income	130		104		328		273

Dividends on preferred stock								Dividends on preferred stock	(1)		(1)		(1)		(1)

Retained earnings, end of period	Retained earnings, end of period		3,388			2,846		Retained earnings, end of period	3,517		2,949		3,517		2,949

Total Shareholders’ Equity	Total Shareholders’ Equity		$	6,366		$	5,809	Total Shareholders’ Equity	$	6,495	$	5,912	$	6,495	$	5,912

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)

~~March 31,~~June 30, 2023

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 has other subsidiaries that conduct other activities, such as providing shared services.

•Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri.

•Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois.

•ATXI operates a FERC rate-regulated electric transmission business in the MISO.

Ameren’s and Ameren Missouri’s financial statements are prepared on a consolidated basis and therefore include the accounts of their majority-owned subsidiaries. All intercompany transactions have been eliminated. Ameren Missouri’s subsidiaries were created for the ~~ownership~~acquisition of renewable generation projects. Ameren Illinois has no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.

Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. The results of operations for an interim period may not give a true indication of results that may be expected for a full year. These financial statements should be read in conjunction with the financial statements and accompanying notes included in the Form 10-K.

Variable Interest Entities

As of ~~March 31,~~June 30, 2023, and December 31, 2022, Ameren had unconsolidated variable interests ~~as a limited partner~~ in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $72 million and $68 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Any earnings or losses related to these investments are included in “Other Income, Net” on Ameren’s consolidated statement of income and comprehensive income. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of ~~March 31,~~June 30, 2023, ~~the~~Ameren’s maximum exposure to loss related to these variable interests is limited to ~~the~~its investment ~~in these partnerships~~ of $72 million plus associated outstanding funding commitments of ~~$17~~$16 million.

COLI

Ameren and Ameren Illinois have COLI, which is recorded at the net cash surrender value. The net cash surrender value is the amount that can be realized under the insurance policies at the balance sheet date. As of ~~March 31,~~June 30, 2023, the cash surrender value of COLI at Ameren and Ameren Illinois was ~~$254~~$255 million (December 31, 2022 – $246 million) and ~~$120~~$122 million (December 31, 2022 – $118 million), respectively, while total borrowings against the policies were ~~$110~~$115 million (December 31, 2022 – $110 million) at both Ameren and Ameren Illinois. Ameren and Ameren Illinois have the right to offset the borrowings against the cash surrender value of the policies and, consequently, present the net asset in “Other assets” on their respective balance sheets. The net cash surrender value of Ameren’s COLI is affected by the investment performance of a separate account in which Ameren holds a beneficial interest.

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NOTE 2 – RATE AND REGULATORY MATTERS

Below is a summary of updates to significant regulatory proceedings and related legal proceedings. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K for additional information and a summary of our regulatory frameworks. We are unable to

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predict the ultimate outcome of these matters, the timing of final decisions of the various agencies and courts, or the impact on our results of operations, financial position, or liquidity.

Missouri

~~2022~~June 2023 MoPSC Electric ~~Service Regulatory~~ Rate ~~Review~~Order

In ~~August 2022, Ameren Missouri filed a request with~~June 2023, the MoPSC ~~seeking approval to increase its annual revenues for~~issued an order in Ameren Missouri’s 2022 electric service ~~by $316 million. In April 2023, Ameren Missouri, the MoPSC staff, the MoOPC, and certain intervenors filed~~regulatory rate review, approving a nonunanimous stipulation and ~~agreement with the MoPSC~~agreement. The order resulted in an increase of $140 million to ~~increase~~ Ameren Missouri’s annual ~~revenues~~revenue requirement for electric ~~service by $140 million.~~retail service. The ~~remaining intervenors~~approved revenue requirement is based on infrastructure investments as of December 31, 2022, and included an extension of the depreciable lives of the Sioux Energy Center’s assets from 2028 to 2030. The order did not ~~object to the agreement. The stipulation and agreement, which is subject to MoPSC approval, did not~~explicitly specify an ~~allowed~~ ROE, capital structure, or rate ~~base, or any rate base disallowances.~~base. The ~~stipulation and agreement includes~~order provides for the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable energy standard costs that the MoPSC previously authorized in earlier electric rate orders, as well as the use of an electric property tax tracker. It also includes a tracker for ~~future~~the utilization of production and investment tax credits ~~and~~or proceeds from the sale of tax credits allowed under the IRA. For additional information regarding the property tax tracker and the IRA, see Note 2 – Rate and Regulatory Matters and Note 12 – Income Taxes under Part II, Item 8, in the Form 10-K.

~~A decision~~ The order increased the annualized base level of net energy costs pursuant to the FAC by approximately $40 million from the ~~MoPSC~~base level established in the MoPSC’s December 2021 electric rate order. The order also changed annualized depreciation, regulatory asset and liability amortization amounts, and the base level of expenses for trackers. On an annualized basis, these changes reflect approximate increases in “Depreciation and amortization” of $90 million and “Other income, net”, of $100 million, related to non-service pension and postretirement benefit income, on ~~the nonunanimous stipulation~~Ameren’s and ~~agreement is expected by June 2023, with~~Ameren Missouri’s consolidated statements of income. The new rates ~~expected to take effect~~became effective on July 1,9, 2023. Ameren Missouri cannot predict whether the MoPSC will approve the stipulation and agreement, or, if approved, whether any application for rehearing or appeal will be filed, or the outcome if so filed. In addition, if the MoPSC does not approve the stipulation and agreement, Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient for Ameren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.

Solar Generation Facilities

InDuring 2022 and 2023, Ameren Missouri, ~~through its~~and certain subsidiaries of Ameren Missouri, entered into ~~build-transfer~~ agreements to acquire ~~after construction, the~~and/or construct various solar ~~facilities below.~~generation facilities. The following table provides information with respect to each ~~build-transfer~~ agreement:

Boomtown

~~Boomtown~~ Solar Project(a)

Huck Finn

Solar Project(b)

Split Rail

Solar Project(c)

Cass County

Solar Project(c)

Vandalia

Solar Project(c)

Bowling Green

Solar Project(c)

Agreement ~~date~~

~~February 2022~~type

~~June 2022~~

~~Developer~~

~~Invenergy Renewables, LLC~~Build-transfer

~~EDF Renewables, Inc.~~Build-transfer

Build-transfer

Development-transfer(d)

Self-build(e)

Facility size

150-MW

200-MW

300-MW

150-MW

~~200-MW~~

~~Location~~50-MW

~~Southeastern Illinois~~

~~Central Missouri~~50-MW

Status of MoPSC CCN

Approved April 2023

Approved February 2023

Filed June 2023(f)

Status of FERC approval of acquisition

Requested May 2023

Received March 2023

Expect to request by ~~mid-2023~~mid-2024

~~Received March 2023~~Not applicable

Not applicable

~~Expected~~Earliest completion date~~(c)~~(g)(h)

~~As early as fourth~~Fourth quarter 2024

Mid-2026

Fourth quarter 2024

Fourth quarter 2025

First quarter 2026

(a)The Boomtown Solar Project is expected to support Ameren Missouri’s transition to renewable energy generation and serve customers under the Renewable Solutions Program discussed below.

(b)The Huck Finn Solar Project represents approximately $0.35 billion of capital expenditures and is expected to support Ameren Missouri’s compliance with the state of Missouri’s ~~requirement of achieving 15% of retail sales from~~ renewable energy ~~sources, of which 2% must~~standard. Investments in the project will be ~~derived from solar energy sources.~~eligible for recovery under the RESRAM.

(c)~~The~~These solar projects are expected to support Ameren Missouri’s transition to renewable energy generation.

(d)Ameren Missouri entered into an agreement to acquire the Cass County Solar Project, which includes project design, land rights, and engineering, supply, and construction agreements for a solar generation facility. Ameren Missouri will construct the facility after obtaining a CCN from the MoPSC and acquiring the project. Acquisition of the project is expected by mid-2024.

(e)Ameren Missouri entered into engineering, supply, and construction agreements to construct these solar projects.

(f)Ameren Missouri expects decisions by the MoPSC in the first quarter of 2024.

(g)Expected completion dates may be impacted by ~~the timing of FERC approval for the Boomtown Solar Project and~~ potential sourcing issues resulting from a United States Department of Commerce investigation of solar panel components imported from four Southeast Asian countries initiated in March 2022 and the detention of certain solar panel components sourced from China as a result of the Uyghur Forced Labor Prevention Act that became effective in June 2022.

(h)Expected completion dates are dependent on the timing of regulatory approvals, among other things.

Renewable Solutions Program

The April 2023 MoPSC order approving the CCN for the Boomtown Solar Project also approved Ameren Missouri’s Renewable Solutions Program and a tariff related to participation in the program. The program will allow certain commercial, industrial, and governmental customers who enroll in the program to receive up to 100% of their energy from renewable resources.

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MoPSC Staff Review of Planned Rush Island Energy Center Retirement

In February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center as a result of the NSR and Clean Air Act Litigation discussed in Note 9 – Commitments and Contingencies. The MoPSC staff’s review includes potential impacts on the reliability and cost of Ameren Missouri’s service to its customers; Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement; and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement of the Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. In Ameren Missouri’s electric service regulatory rate review discussed above, the MoPSC staff recommended a lower rate base for the Rush Island Energy Center claiming imprudent actions by Ameren Missouri. While the nonunanimous stipulation and agreement approved by the June 2023 MoPSC electric rate order did not specify any rate base disallowance, it did not preclude parties to the agreement from raising issues regarding the prudence of Ameren Missouri’s actions and decisions with regard to the energy center in future proceedings. Ameren Missouri is unable to predict the results of this matter. Results of the review could be used

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in other MoPSC proceedings, which could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri.

MEEIA

In March 2023, Ameren Missouri filed a proposed three-year customer energy-efficiency plan with the MoPSC under the MEEIA. ~~This filing~~As a result of a nonunanimous stipulation and agreement filed with the MoPSC in August 2023 by Ameren Missouri, the MoPSC staff, and the MoOPC to extend Ameren Missouri’s MEEIA 2019 program through 2024, Ameren Missouri expects to revise the proposed a three-year plan in 2024. The stipulation and agreement, which is subject to MoPSC approval, includes the establishment of a portfolio of customer energy-efficiency programs ~~along with the continued use of the MEEIA rider, which allows~~for 2024 and performance incentives that would provide Ameren Missouri an opportunity to ~~collect from, or refund to, customers any difference~~earn revenues, including $12 million if Ameren Missouri achieves certain energy-efficiency goals in ~~actual MEEIA program costs and related lost electric margins and the amounts collected from customers.~~2024. If ~~the plan is~~ approved, Ameren Missouri ~~intends~~expects to invest ~~$122~~$76 million ~~annually~~ in ~~the proposed customer~~ energy-efficiency programs from 2024 to 2026. In addition, Ameren Missouri requested performance incentives applicable to each plan year to earn additional revenues by achieving certain customer energy-efficiency and target spending goals. If 100% of the goals are achieved, Ameren Missouri would earn additional revenues totaling $55 million over the three-year plan. Ameren Missouri also requested additional performance incentives applicable to each plan year totaling up to $14 million over the three-year plan, if Ameren Missouri exceeds 100% of the goals.in 2024. The MoPSC is under no deadline to issue an order in this proceeding.

Illinois

MYRP

In January 2023, Ameren Illinois filed an MYRP with the ICC, which was subsequently revised in July 2023, to be used in setting electric distribution service rates for 2024 through 2027. Under the MYRP, the ICC would approve base rates for electric distribution service to be charged to customers for each calendar year of the four-year period. In July 2023, the ICC staff submitted its recommendation for electric distribution service rates for 2024 through 2027 under the MYRP. The following table includes the forecasted revenue requirement, the requested and recommended ROE, the requested and recommended capital structure common equity percentage, and the forecasted average annual rate base for 2024 through 2027, as reflected in Ameren Illinois’ ~~MYRP:~~revised MYRP filing and the ICC staff’s filing:


Year	Year	Forecasted Revenue Requirement (in millions)	Requested ROE	Requested Capital Structure Common Equity Percentage(a)	Forecasted Average Annual Rate Base (in billions)	Year	Forecasted Revenue Requirement (in millions)(a)	Requested/Recommended ROE(b)(c)	Requested/Recommended Capital Structure Common Equity Percentage(b)(d)	Forecasted Average Annual Rate Base (in billions)
Ameren Illinois’ July 2023 Filing:						Ameren Illinois’ July 2023 Filing:
2024	2024	$1,282	10.5%	53.99%	$4.3	2024	$1,291	10.5%	53.99%	$4.3
2025	2025	$1,373	10.5%	53.97%	$4.6	2025	$1,387	10.5%	53.97%	$4.6
2026	2026	$1,477	10.5%	54.02%	$5.0	2026	$1,484	10.5%	54.02%	$4.9
2027	2027	$1,556	10.5%	54.03%	$5.3	2027	$1,560	10.5%	54.03%	$5.2
ICC Staff’s July 2023 Filing:						ICC Staff’s July 2023 Filing:
2024						2024	$1,211	8.9%	50.00%	$4.1
2025						2025	$1,292	8.9%	50.00%	$4.4
2026						2026	$1,371	8.9%	50.00%	$4.6
2027						2027	$1,429	8.9%	50.00%	$4.8

(a)If an initial rate increase phase-in provision, discussed below, is approved by the ICC, it would not affect the annual revenue requirement, but would affect the timing of associated recovery from customers.

(b)ROE and capital structure common equity percentage requested in Ameren Illinois’ July 2023 filing and recommended in the ICC staff’s July 2023 filing.

(c)The ICC staff filing recommended an ROE based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points, to be updated annually for each applicable calendar year of the MYRP. An estimated ROE of 8.9% was used to calculate the forecasted revenue requirements in the ICC staff filing, which is based on the average monthly yields of the 30-year United States Treasury bonds for 2022. The ICC staff proposed that variances in the revenue requirement resulting from a change in the ROE would be excluded from the reconciliation cap discussed below.

(d)A capital structure of up to and including 50% common equity is deemed prudent and reasonable by law. A higher equity ratio requires specific ICC approval.

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Under an MYRP, the IETL permits any initial rate increase to be phased in, with at least 50% of the first annual period’s approved rate increase reflected in rates in the first annual period, with the remaining portion deferred as a regulatory asset that earns a return at the applicable WACC and is collected from customers over a period not to exceed two years beginning within one year after the second annual period’s rates are effective. Ameren Illinois’ revised MYRP filing utilizes this phase-in provision and proposes to defer 50% of the requested 2024 rate increase of ~~$171~~$179 million as a regulatory asset to be collected from customers in 2026. Ameren Illinois recognizes revenues that have been authorized for rate recovery when amounts are expected to be collected from customers within two years from the end of an applicable year. The ICC staff’s filing does not utilize a phase-in provision. An ICC decision in this proceeding is required by December 2023, with new rates effective starting in January 2024. Ameren Illinois cannot predict the level of any electric distribution service rate change the ICC may approve, or whether any rate change that may eventually be approved will be sufficient for Ameren Illinois to recover its costs to the extent those costs are subject to and exceed the reconciliation cap discussed below and earn a reasonable return on its investments when the rate change goes into effect.

The MYRP also allows Ameren Illinois to reconcile its actual revenue requirement, as adjusted for certain cost variations, to ICC-approved electric distribution service rates on an annual basis, subject to a reconciliation cap. The reconciliation cap limits the annual adjustment to 105% of the annual revenue requirement approved by the ICC. Certain variations from forecasted costs would be excluded from the reconciliation cap, including those associated with major storms; new business and facility relocations; changes in the timing of certain expenditures or investments into or out of the applicable calendar year; and changes in interest rates, income taxes, taxes other than income taxes, pension and other post-retirement benefits costs, and amortization of certain assets. The reconciliation cap also excludes costs recovered through riders outside of base rates, such as riders for electric energy-efficiency investments, power procurement and transmission services, renewable energy credit compliance, zero emission credits, certain environmental costs, and bad debt write-offs, among others. Ameren Illinois’ existing riders will remain effective and electric distribution service revenues will continue to be decoupled from sales volumes under the MYRP. The actual revenue requirement for a particular year would incorporate Ameren Illinois’ year-end rate base and actual capital structure for such year, provided that the common equity ratio in such capital structure may not exceed that approved by the ICC in the MYRP. Excluding the phase-in of the initial rate increase discussed above, and subject to the reconciliation cap, if a given year’s revenue amount collected from customers varies from the approved revenue requirement, an adjustment would be made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance would then be collected from, or refunded to, customers within two years from the end of the applicable annual period.

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Under the MYRP, the ROE approved by the ICC will be subject to annual adjustments ~~during the four-year period~~ based on ~~seven~~ performance metrics. In 2022, the ICC issued an order approving total ROE incentives and penalties of 24 basis points, allocated among ~~the~~ seven performance metrics. These performance metrics include improvements in service reliability in both the frequency and duration of outages, a reduction in peak loads, an increased percentage of spend with diverse suppliers, a reduction in disconnections for certain customers, and improved timeliness in response to customer requests for interconnection of distributed energy resources. These performance metrics will apply annually from 2024 through 2027 under the MYRP, and the impact of any incentives and penalties will be excluded from the reconciliation cap described above.

2022 Electric Distribution Revenue Requirement Reconciliation Adjustment Request

In April 2023, Ameren Illinois filed for a reconciliation adjustment to its 2022 electric distribution service revenue requirement with the ~~ICC,~~ICC. In July 2023, Ameren Illinois filed a revised reconciliation adjustment, requesting recovery of ~~$127~~$125 million. The reconciliation adjustment reflects Ameren Illinois’ actual 2022 recoverable costs, year-end rate base, and capital structure, which was composed of 53.99% common equity. In June 2023, the ICC staff submitted its calculation of the reconciliation adjustment, recommending recovery of $109 million, which is based on a capital structure composed of 50% common equity. An ICC decision in this proceeding is required by December 2023, and any approved adjustment would be collected from customers in 2024.

Electric Customer Energy-Efficiency Investments

In May 2023, Ameren Illinois filed its annual electric energy-efficiency formula rate update to increase its rates by $27 million with the ICC. An ICC decision in this proceeding is required by December 2023, with new rates effective January 2024.

2023 Natural Gas Delivery Service Regulatory Rate Review

In January 2023, Ameren Illinois filed a request with the ICC seeking approval to increase its annual revenues for natural gas delivery ~~service~~service. In July 2023, Ameren Illinois filed a revised request seeking to increase its annual revenues by ~~$160~~$148 million, which ~~included~~includes an estimated $77 million of annual revenues that would otherwise be recovered under the QIP and other riders. The request is based on a ~~10.7%~~10.3% allowed ROE, a capital structure composed of 53.99% common equity, and a rate base of $2.9 billion. In an attempt to reduce regulatory lag, Ameren Illinois used a 2024 future test year in this proceeding. In July 2023, the ICC staff recommended an increase to annual revenues for natural gas delivery service of $128 million, which includes an estimated $77 million of annual revenues that would otherwise be recovered under the QIP and other riders. The recommendation is based on a 9.89% ROE, a capital structure composed of 50% common equity, and a rate base of $2.9 billion. Other intervenors recommended an increase to annual revenues ranging from

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$98 million to $106 million, which were based on varying rate base amounts, a 9.5% ROE, and a capital structure composed of 52% common equity. A decision by the ICC in this proceeding is required by late November 2023, with new rates expected to be effective in early December 2023. Ameren Illinois cannot predict the level of any delivery service rate change the ICC may approve, nor whether any rate change that may eventually be approved will be sufficient to enable Ameren Illinois to recover its costs and to earn a reasonable return on investments when the rate changes go into effect.

RTO Cost-Benefit Study

In July 2022, an Illinois law prohibiting the state’s oversight of certain electric utilities’ choice of RTO membership ceased to be effective. Given the change in law and the high prices resulting from MISO’s April 2022 capacity auction, the ICC issued an order requiring Ameren Illinois to perform a cost-benefit study of continued participation in the MISO compared to participation in PJM Interconnection LLC, another RTO. In July 2023, Ameren Illinois filed its cost-benefit study with the ICC. The cost-benefit study examined the impacts of participation in each RTO, including reliability, resiliency, affordability, and environmental impacts, among other things, for a period of five to 10 years, beginning June 2024. The study concluded that continued participation in the MISO was prudent and more cost-beneficial than participation in PJM Interconnection LLC. Comments on the study are due by late August 2023. The ICC is under no obligation to issue an order related to the cost-benefit study.

Federal

FERC Complaint Cases

Since November 2013, the allowed base ROE for FERC-regulated transmission rate base under the MISO tariff has been subject to customer complaint cases and has been changed by various FERC orders. In May 2020, the FERC issued an order, which set the allowed base ROE to 10.02%, and required refunds, with interest, for the periods November 2013 to February 2015 and from late September 2016 forward. Ameren and Ameren Illinois paid these refunds, including interest, by March 31, 2022. In June and July 2020, Ameren Missouri, Ameren Illinois, and ATXI, as well as various customers, petitioned the United States Court of Appeals for the District of Columbia Circuit for review of the May 2020 order, challenging certain aspects of the new ROE methodology established. The petition filed by Ameren Missouri, Ameren Illinois, and ATXI challenged the refunds required for the period from September 2016 to May 2020. In August 2022, the court issued a ruling that granted the customers’ petition for review, vacated the FERC’s previous MISO ROE-determining orders, and remanded the proceedings to the FERC. The court elected not to rule on the issues raised by Ameren Missouri, Ameren Illinois, and ~~ATXI; however, they may raise the issues again in the future.~~ATXI. The currently allowed base ROE of 10.02% will remain effective for customer billings, but is subject to refund if the base ROE is changed by the FERC in a future order. The FERC is under no deadline to issue an order related to these proceedings. A ~~50 basis point~~50-basis-point change in the FERC-allowed ROE would affect Ameren’s and Ameren Illinois’ annual revenue by an estimated $19 million and $13 million, respectively, based on each company’s 2023 projected rate base.

NOTE 3 – SHORT-TERM DEBT AND LIQUIDITY

The liquidity needs of the Ameren Companies are typically supported through the use of available cash, drawings under committed credit agreements, commercial paper issuances, and, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, in the Form 10-K for a description of our indebtedness provisions and other covenants as well as a description of money pool arrangements.

Short-term Borrowings

The Missouri Credit Agreement and the Illinois Credit Agreement are available to support issuances under Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper programs, respectively, subject to borrowing sublimits, and the issuance of letters of credit. As of ~~March 31,~~June 30, 2023, based on commercial paper outstanding and letters of credit issued under the Credit Agreements, along with cash and cash equivalents, the net liquidity available to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, was ~~$1.4~~$1.3 billion. The Ameren Companies were in compliance with the covenants in their Credit Agreements as of ~~March 31,~~June 30, 2023. As of ~~March 31,~~June 30, 2023, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were ~~59%~~60%, 51%, and 45% for Ameren, Ameren Missouri, and Ameren Illinois, respectively.

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The following table presents commercial paper outstanding, net of issuance discounts, as of ~~March 31,~~June 30, 2023, and December 31, 2022. There were no borrowings outstanding under the Credit Agreements as of ~~March 31,~~June 30, 2023, or December 31, 2022.


		March 31, 2023		December 31, 2022			June 30, 2023		December 31, 2022
Ameren (parent)	Ameren (parent)	$	727	$	477	Ameren (parent)	$	839	$	477
Ameren Missouri	Ameren Missouri	197		329		Ameren Missouri	373		329
Ameren Illinois	Ameren Illinois	324		264		Ameren Illinois	117		264
Ameren consolidated	Ameren consolidated	$	1,248	$	1,070	Ameren consolidated	$	1,329	$	1,070

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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 and borrowings under the Credit Agreements in the aggregate for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022:


		Ameren (parent)			Ameren Missouri			Ameren Illinois			Ameren Consolidated				Ameren (parent)			Ameren Missouri			Ameren Illinois			Ameren Consolidated
2023	2023													2023
Average daily amount outstanding	Average daily amount outstanding	$	506		$	436		$	233		$	1,175		Average daily amount outstanding	$	595		$	343		$	230		$	1,168

Weighted-average interest rate	Weighted-average interest rate	4.89		%	4.86		%	4.89		%	4.88		%	Weighted-average interest rate	5.14		%	5.04		%	5.10		%	5.10		%
Peak amount outstanding during period(a)	Peak amount outstanding during period(a)	$	728		$	592		$	325		$	1,381		Peak amount outstanding during period(a)	$	841		$	592		$	450		$	1,381
Peak interest rate	Peak interest rate	5.55		%	5.55		%	5.60		%	5.60		%	Peak interest rate	5.55		%	5.55		%	5.60		%	5.60		%
2022	2022													2022
Average daily amount outstanding	Average daily amount outstanding	$	282		$	408		$	99		$	789		Average daily amount outstanding	$	374		$	271		$	57		$	702

Weighted-average interest rate	Weighted-average interest rate	0.41		%	0.44		%	0.33		%	0.41		%	Weighted-average interest rate	0.87		%	0.65		%	0.47		%	0.75		%
Peak amount outstanding during period(a)	Peak amount outstanding during period(a)	$	466		$	539		$	142		$	1,101		Peak amount outstanding during period(a)	$	595		$	539		$	142		$	1,101
Peak interest rate	Peak interest rate	1.05		%	1.06		%	1.15		%	1.15		%	Peak interest rate	2.05		%	2.05		%	2.05		%	2.05		%

(a)The timing of peak outstanding commercial paper issuances and borrowings under the Credit Agreements varies by company. Therefore, the sum of individual company peak amounts may not equal the Ameren consolidated peak for the period.

Money Pools

Ameren has money pool agreements with and among its subsidiaries to coordinate and provide for certain short-term cash and working capital requirements. The average interest rate for borrowings under the utility money pool for the three and six months ended ~~March 31,~~June 30, 2023, was ~~4.80%~~5.28% and 5.04%, respectively (2022 – ~~0.39%)~~0.98% and 0.69%, respectively). See Note 8 – Related-party Transactions for the amount of interest income and expense from the utility money pool arrangements recorded by Ameren Missouri and Ameren Illinois for the three and six months ended ~~March 31,~~June 30, 2023 and 2022.

NOTE 4 – LONG-TERM DEBT AND EQUITY FINANCINGS

Ameren

For the three and six months ended ~~March 31,~~June 30, 2023, Ameren issued a total of 0.1 million and 0.2 million shares of common stock, respectively, under its DRPlus and 401(k) plan, and received proceeds of $5$4 million and $16 million, respectively. As of June 30, 2023, Ameren had a receivable of $7 ~~million.~~million related to its DRPlus and 401(k) plan. In addition, in the first quarter of 2023, Ameren issued 0.5 million shares of common stock valued at $37 million upon the settlement of stock-based compensation awards.

There were no shares issued under the ATM program for the three and six months ended ~~March 31,~~June 30, 2023. As of ~~March 31,~~June 30, 2023, Ameren had approximately ~~$980~~$910 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of ~~March 31,~~June 30, 2023, discussed below. ~~As of April 30, 2023, Ameren had multiple forward sale agreements that could be settled under the ATM program with various counterparties relating to 3.8 million shares of common stock.~~

The forward sale agreements outstanding as of ~~March 31,~~June 30, 2023, can be settled at Ameren’s discretion on or prior to dates ranging from January 10, 2024 to ~~October 3, 2024.~~February 28, 2025. On a settlement date or dates, if Ameren elects to physically settle a forward sale agreement, Ameren will issue shares of common stock to the counterparties at the then-applicable forward sale price. The initial forward sale price for the agreements ranged from ~~$89.31~~$81.83 to ~~$94.80,~~$94.63, with an average initial forward sale price of ~~$92.66.~~$91.23. Each initial forward sale price is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75 basis points, and will be subject to decrease on certain dates specified in the forward sale agreements by specified amounts related to expected dividends on shares of the common stock during the term of the forward sale agreements. If the overnight bank funding rate is less than the spread on any day, the interest rate factor will result in a reduction of the forward sale price. The forward sale agreements will be physically settled unless Ameren elects to settle in cash or to net share settle. At ~~March 31,~~June 30, 2023, Ameren could have settled the forward sale agreements with physical delivery of ~~3.4~~4.3 million shares of common stock to the respective counterparties in exchange for cash of ~~$317~~$389 million. Alternatively, the forward sale agreements could have also been settled at ~~March 31,~~June 30, 2023, with the counterparties delivering approximately ~~$21~~$41 million of cash or approximately ~~0.2~~0.5 million shares of common stock to Ameren. In connection with the forward sale agreements outstanding at June 30, 2023, the various counterparties, or their affiliates, borrowed from third parties and sold ~~3.4~~4.3 million shares of common stock. The gross sales price of these

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shares totaled ~~$321~~$392 million. In connection with ~~such~~ sales in the three months ended June 30, 2023, the counterparties were deemed to have received commissions of $3less than $1 million. Ameren has not received any proceeds from such sales of borrowed shares. The forward sale agreements have been classified as equity transactions.

~~In April 2023, Ameren entered into a forward sale agreement under the ATM program relating to 0.4 million shares~~

Table of ~~common stock. The April 2023 forward sale agreement can be settled at Ameren’s discretion on or prior to January 14, 2025. The initial forward sale price was $89.11.~~Contents

Ameren Missouri

In January 2023, Ameren Missouri and Audrain County mutually agreed to terminate a financing obligation agreement related to the CT energy center in Audrain County, which was scheduled to expire in December 2023. No cash was exchanged in connection with the termination of the agreement as the $240 million principal amount of the financing obligation due from Ameren Missouri was equal to the amount of bond service payments due to Ameren Missouri. Ownership of the energy center was transferred to Ameren Missouri in January 2023, at which time the property, plant, and equipment became subject to the lien of the Ameren Missouri mortgage bond indenture.

In March 2023, Ameren Missouri issued $500 million of 5.45% first mortgage bonds due March 2053, with interest payable semiannually on March 15 and September 15 of each year, beginning September 15, 2023. Ameren Missouri received net proceeds of $495 million, which were used for capital expenditures and to repay short-term debt.

Ameren Illinois

In May 2023, Ameren Illinois issued $500 million of 4.95% first mortgage bonds due June 2033, with interest payable semiannually on June 1 and December 1 of each year, beginning December 1, 2023. Ameren Illinois received net proceeds of $495 million, which were used to repay $100 million principal amount of its 0.375% first mortgage bonds that matured in June 2023 and short-term debt.

Indenture Provisions and Other Covenants

See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, in the Form 10-K for a description of our indenture provisions and other covenants, as well as restrictions on the payment of dividends. At ~~March 31,~~June 30, 2023, 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 ~~March 31,~~June 30, 2023, none of the Ameren Companies had any material off-balance-sheet financing arrangements, other than Ameren’s investment in variable interest entities and the multiple forward sale agreements under the ATM program relating to common stock. See Note 1 – Summary of Significant Accounting Policies for further detail concerning variable interest entities.

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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 six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months					Three Months				Six Months
			2023		2022				2023		2022		2023		2022
Ameren:	Ameren:							Ameren:

Allowance for equity funds used during construction	Allowance for equity funds used during construction		$	9	$	8		Allowance for equity funds used during construction	$	14	$	11	$	23	$	19
Interest income on industrial development revenue bonds	Interest income on industrial development revenue bonds		1		6			Interest income on industrial development revenue bonds	—		6		1		12

Non-service cost components of net periodic benefit income(a)	Non-service cost components of net periodic benefit income(a)		64		46			Non-service cost components of net periodic benefit income(a)	63		47		127		93
Miscellaneous income	Miscellaneous income		9		4			Miscellaneous income	11		5		20		9
Earnings related to equity method investments	Earnings related to equity method investments		2		3			Earnings related to equity method investments	—		1		2		4
Donations	Donations		(2)		(2)			Donations	(2)		(2)		(4)		(4)
Miscellaneous expense	Miscellaneous expense		(5)		(5)			Miscellaneous expense	(4)		(6)		(9)		(11)
Total Other Income, Net	Total Other Income, Net		$	78	$	60		Total Other Income, Net	$	82	$	62	$	160	$	122
Ameren Missouri:	Ameren Missouri:							Ameren Missouri:

Allowance for equity funds used during construction	Allowance for equity funds used during construction		$	4	$	4		Allowance for equity funds used during construction	$	8	$	6	$	12	$	10
Interest income on industrial development revenue bonds	Interest income on industrial development revenue bonds		1		6			Interest income on industrial development revenue bonds	—		6		1		12

Non-service cost components of net periodic benefit income(a)	Non-service cost components of net periodic benefit income(a)		14		14			Non-service cost components of net periodic benefit income(a)	14		14		28		28
Miscellaneous income	Miscellaneous income		4		2			Miscellaneous income	3		1		7		3
Donations	Donations		(1)		(1)			Donations	(1)		(1)		(2)		(2)
Miscellaneous expense	Miscellaneous expense		(3)		(2)			Miscellaneous expense	(2)		(2)		(5)		(4)
Total Other Income, Net	Total Other Income, Net		$	19	$	23		Total Other Income, Net	$	22	$	24	$	41	$	47
Ameren Illinois:	Ameren Illinois:							Ameren Illinois:

Allowance for equity funds used during construction	Allowance for equity funds used during construction		$	4	$	4		Allowance for equity funds used during construction	$	6	$	5	$	10	$	9

Non-service cost components of net periodic benefit income	Non-service cost components of net periodic benefit income		31		21			Non-service cost components of net periodic benefit income	31		21		62		42
Miscellaneous income	Miscellaneous income		5		2			Miscellaneous income	7		3		12		5
Donations	Donations		(1)		(1)			Donations	(1)		(1)		(2)		(2)
Miscellaneous expense	Miscellaneous expense		(2)		(2)			Miscellaneous expense	(2)		(3)		(4)		(5)
Total Other Income, Net	Total Other Income, Net		$	37	$	24		Total Other Income, Net	$	41	$	25	$	78	$	49

(a)For the three and six months ended ~~March 31,~~June 30, 2023 ~~and 2022,~~ the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $17 million and $6$34 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 $5 million and $11 million, respectively, for the three and six months ended June 30, 2022. See Note ~~11–~~11 – Retirement Benefits for additional information.

NOTE 6 – DERIVATIVE FINANCIAL INSTRUMENTS

We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following:

•an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices;

•market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory;

•actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays; and

•actual off-system sales revenues that differ from anticipated revenues.

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.

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If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether the resulting gains or losses qualify for regulatory deferral. Derivative contracts that qualify for regulatory deferral are

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recorded at fair value, with changes in fair value recorded as regulatory assets or liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and liabilities are probable of recovery, or refund, through future rates charged to customers. Regulatory assets and liabilities are amortized to operating income as related losses and gains are reflected in rates charged to customers. Therefore, gains and losses on these derivatives have no effect on operating income. As of ~~March 31,~~June 30, 2023, and December 31, 2022, all contracts that met the definition of a derivative and were not eligible for the NPNS exception received regulatory deferral. Cash flows for all derivative financial instruments are classified in cash flows from operating activities.

The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of ~~March 31,~~June 30, 2023, and December 31, 2022. As of ~~March 31,~~June 30, 2023, these contracts extended through October ~~2025,~~2026, October 2029, May 2032 and March 2024 for fuel oils, natural gas, power and uranium, respectively.


		Quantity (in millions)							Quantity (in millions)
		March 31, 2023			December 31, 2022				June 30, 2023			December 31, 2022
Commodity	Commodity	Ameren Missouri	Ameren Illinois	Ameren	Ameren Missouri	Ameren Illinois	Ameren	Commodity	Ameren Missouri	Ameren Illinois	Ameren	Ameren Missouri	Ameren Illinois	Ameren
Fuel oils (in gallons)	Fuel oils (in gallons)	18	—	18	18	—	18	Fuel oils (in gallons)	18	—	18	18	—	18
Natural gas (in mmbtu)	Natural gas (in mmbtu)	60	185	245	48	157	205	Natural gas (in mmbtu)	57	218	275	48	157	205
Power (in MWhs)	Power (in MWhs)	1	6	7	1	6	7	Power (in MWhs)	1	5	6	1	6	7
Uranium (pounds in thousands)	Uranium (pounds in thousands)	186	—	186	514	—	514	Uranium (pounds in thousands)	186	—	186	514	—	514

The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of ~~March 31,~~June 30, 2023, and December 31, 2022:


				March 31, 2023					December 31, 2022									June 30, 2023						December 31, 2022
		Balance Sheet Location		Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri		Ameren Illinois		Ameren		Balance Sheet Location	Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri		Ameren Illinois		Ameren

Fuel oils	Fuel oils	Other current assets	$	8	$	—	$	8		$	13	$	—	$	13	Fuel oils	Other current assets	$	5	$	—	$	5		$	13	$	—	$	13
		Other assets		2		—		2			3		—		3		Other assets	1		—		1			3		—		3

Natural gas	Natural gas	Other current assets		1		5		6			7		23		30	Natural gas	Other current assets	2		8		10			7		23		30
		Other assets		8		8		16			9		11		20		Other assets	5		5		10			9		11		20

Power	Power	Other current assets		5		—		5			14		2		16	Power	Other current assets	15		—		15			14		2		16
		Other assets		—		1		1			—		4		4		Other assets	—		—		—			—		4		4

Uranium	Uranium	Other current assets		1		—		1			2		—		2	Uranium	Other current assets	2		—		2			2		—		2
		Other assets		—		—		—			1		—		1		Other assets	—		—		—			1		—		1
		Total assets	$	25	$	14	$	39		$	49	$	40	$	89		Total assets	$	30	$	13	$	43		$	49	$	40	$	89

Fuel oils																Fuel oils	Other current liabilities	$	1	$	—	$	1		$	—	$	—	$	—
																	Other deferred credits and liabilities	1		—		1			—		—		—
Fuel oils		Other deferred credits and liabilities	$	1	$	—	$	1		$	—	$	—	$	—

Natural gas	Natural gas	Other current liabilities		9		33		42			7		20		27	Natural gas	Other current liabilities	8		27		35			7		20		27
		Other deferred credits and liabilities		5		12		17			2		9		11		Other deferred credits and liabilities	8		19		27			2		9		11

Power	Power	Other current liabilities		17		10		27			59		2		61	Power	Other current liabilities	13		10		23			59		2		61
		Other deferred credits and liabilities		—		43		43			—		37		37		Other deferred credits and liabilities	—		58		58			—		37		37

		Total liabilities	$	32	$	98	$	130		$	68	$	68	$	136		Total liabilities	$	31	$	114	$	145		$	68	$	68	$	136

We believe that entering into master netting arrangements or similar agreements mitigates the level of financial loss that could result from default by allowing net settlement of derivative assets and liabilities. These master netting arrangements allow the counterparties to net settle sale and purchase transactions. Further, collateral requirements are calculated at the master netting arrangement or similar agreement level by counterparty.

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The following table provides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of ~~March 31,~~June 30, 2023, and December 31, 2022:


				Gross Amounts Not Offset in the Balance Sheet									Gross Amounts Not Offset in the Balance Sheet
Commodity Contracts Eligible to be Offset	Commodity Contracts Eligible to be Offset	Gross Amounts Recognized in the Balance Sheet		Derivative Instruments		Cash Collateral Received/Posted(a)		Net Amount		Commodity Contracts Eligible to be Offset	Gross Amounts Recognized in the Balance Sheet		Derivative Instruments		Cash Collateral Received/Posted(a)		Net Amount
March 31, 2023
June 30, 2023										June 30, 2023
Assets:	Assets:									Assets:
Ameren Missouri	Ameren Missouri	$	25	$	9	$	—	$	16	Ameren Missouri	$	30	$	9	$	—	$	21
Ameren Illinois	Ameren Illinois	14		11		—		3		Ameren Illinois	13		9		—		4
Ameren	Ameren	$	39	$	20	$	—	$	19	Ameren	$	43	$	18	$	—	$	25
Liabilities:	Liabilities:									Liabilities:
Ameren Missouri	Ameren Missouri	$	32	$	9	$	16	$	7	Ameren Missouri	$	31	$	9	$	12	$	10
Ameren Illinois	Ameren Illinois	98		11		—		87		Ameren Illinois	114		9		—		105
Ameren	Ameren	$	130	$	20	$	16	$	94	Ameren	$	145	$	18	$	12	$	115
December 31, 2022	December 31, 2022									December 31, 2022
Assets:	Assets:									Assets:
Ameren Missouri	Ameren Missouri	$	49	$	9	$	—	$	40	Ameren Missouri	$	49	$	9	$	—	$	40
Ameren Illinois	Ameren Illinois	40		20		—		20		Ameren Illinois	40		20		—		20
Ameren	Ameren	$	89	$	29	$	—	$	60	Ameren	$	89	$	29	$	—	$	60
Liabilities:	Liabilities:									Liabilities:
Ameren Missouri	Ameren Missouri	$	68	$	9	$	56	$	3	Ameren Missouri	$	68	$	9	$	56	$	3
Ameren Illinois	Ameren Illinois	68		20		—		48		Ameren Illinois	68		20		—		48
Ameren	Ameren	$	136	$	29	$	56	$	51	Ameren	$	136	$	29	$	56	$	51

(a)Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Current collateral assets” and “Other assets” on the balance sheet for Ameren and Ameren Missouri and “Other current assets” and “Other assets” for Ameren Illinois.

Credit Risk

In determining our concentrations of credit risk related to derivative instruments, we review our individual counterparties and categorize each counterparty into groupings according to the primary business in which each engages. As of ~~March 31,~~June 30, 2023, if counterparty groups were to fail completely to perform on contracts, the Ameren Companies’ maximum exposure related to derivative assets, predominantly from financial institutions, would have been immaterial with or without consideration of the application of master netting arrangements or similar agreements and collateral held.

Certain of our derivative instruments contain collateral provisions tied to the Ameren Companies’ credit ratings. If our credit ratings were downgraded below investment grade, or if a counterparty with reasonable grounds for uncertainty regarding our ability to satisfy an obligation requested adequate assurance of performance, additional collateral postings might be required. The additional collateral required is the net liability position allowed under master netting arrangements or similar agreements, assuming (1) the credit risk-related contingent features underlying these arrangements were triggered and (2) those counterparties with rights to do so requested collateral. The following table presents, as of ~~March 31,~~June 30, 2023, the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require:


		Aggregate Fair Value of Derivative Liabilities(a)		Cash Collateral Posted		Potential Aggregate Amount of Additional Collateral Required(b)			Aggregate Fair Value of Derivative Liabilities(a)		Cash Collateral Posted		Potential Aggregate Amount of Additional Collateral Required(b)
Ameren Missouri	Ameren Missouri	$	16	$	—	$	7	Ameren Missouri	$	19	$	—	$	10
Ameren Illinois	Ameren Illinois	45		—		36		Ameren Illinois	46		—		37
Ameren	Ameren	$	61	$	—	$	43	Ameren	$	65	$	—	$	47

(a)Before consideration of master netting arrangements or similar agreements.

(b)As collateral requirements with certain counterparties are based on master netting arrangements or similar agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such arrangements.

NOTE 7 – FAIR VALUE MEASUREMENTS

Fair value is defined as the price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. Fair value measurements are classified in three levels based on the fair value hierarchy as defined by GAAP. See Note 8 – Fair Value Measurements under Part II, Item 8, of the Form 10-K for information related to hierarchy levels and valuation techniques.

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We consider nonperformance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g., collateral). Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in the three and six months ended ~~March 31,~~June 30, 2023 or 2022. At ~~March 31,~~June 30, 2023, and December 31, 2022, the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois.

The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of ~~March 31,~~June 30, 2023, and December 31, 2022:


			March 31, 2023									December 31, 2022											June 30, 2023									December 31, 2022
			Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total					Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total
Assets:	Assets:																				Assets:
Ameren Missouri	Ameren Missouri																				Ameren Missouri
		Derivative assets – commodity contracts:																				Derivative assets – commodity contracts:
		Fuel oils	$	10	$	—	$	—	$	10		$	16	$	—	$	—	$	16			Fuel oils	$	6	$	—	$	—	$	6		$	16	$	—	$	—	$	16
		Natural gas	—		9		—		9			1		15		—		16				Natural gas	—		7		—		7			1		15		—		16
		Power	—		—		5		5			—		—		14		14				Power	—		—		15		15			—		—		14		14
		Uranium	—		—		1		1			—		—		3		3				Uranium	—		—		2		2			—		—		3		3
		Total derivative assets – commodity contracts	$	10	$	9	$	6	$	25		$	17	$	15	$	17	$	49			Total derivative assets – commodity contracts	$	6	$	7	$	17	$	30		$	17	$	15	$	17	$	49
		Nuclear decommissioning trust fund:																				Nuclear decommissioning trust fund:

		Equity securities:																				Equity securities:
		U.S. large capitalization	$	668	$	—	$	—	$	668		$	618	$	—	$	—	$	618			U.S. large capitalization	$	727	$	—	$	—	$	727		$	618	$	—	$	—	$	618
		Debt securities:																				Debt securities:
		U.S. Treasury and agency securities	—		149		—		149			—		137		—		137				U.S. Treasury and agency securities	—		147		—		147			—		137		—		137
		Corporate bonds	—		123		—		123			—		122		—		122				Corporate bonds	—		126		—		126			—		122		—		122

		Other	—		74		—		74			—		70		—		70				Other	—		69		—		69			—		70		—		70
		Total nuclear decommissioning trust fund	$	668	$	346	$	—	$	1,014	(a)	$	618	$	329	$	—	$	947	(a)		Total nuclear decommissioning trust fund	$	727	$	342	$	—	$	1,069	(a)	$	618	$	329	$	—	$	947	(a)
		Total Ameren Missouri	$	678	$	355	$	6	$	1,039		$	635	$	344	$	17	$	996			Total Ameren Missouri	$	733	$	349	$	17	$	1,099		$	635	$	344	$	17	$	996
Ameren Illinois	Ameren Illinois																				Ameren Illinois
		Derivative assets – commodity contracts:																				Derivative assets – commodity contracts:
		Natural gas	$	—	$	10	$	3	$	13		$	1	$	28	$	5	$	34			Natural gas	$	—	$	9	$	4	$	13		$	1	$	28	$	5	$	34
		Power	—		—		1		1			—		—		6		6				Power	—		—		—		—			—		—		6		6
		Total Ameren Illinois	$	—	$	10	$	4	$	14		$	1	$	28	$	11	$	40			Total Ameren Illinois	$	—	$	9	$	4	$	13		$	1	$	28	$	11	$	40
Ameren	Ameren																				Ameren
		Derivative assets – commodity contracts(b)	$	10	$	19	$	10	$	39		$	18	$	43	$	28	$	89			Derivative assets – commodity contracts(b)	$	6	$	16	$	21	$	43		$	18	$	43	$	28	$	89
		Nuclear decommissioning trust fund(c)	668		346		—		1,014		(a)	618		329		—		947		(a)		Nuclear decommissioning trust fund(c)	727		342		—		1,069		(a)	618		329		—		947		(a)
		Total Ameren	$	678	$	365	$	10	$	1,053		$	636	$	372	$	28	$	1,036			Total Ameren	$	733	$	358	$	21	$	1,112		$	636	$	372	$	28	$	1,036
Liabilities:	Liabilities:																				Liabilities:
Ameren Missouri	Ameren Missouri																				Ameren Missouri
		Derivative liabilities – commodity contracts:																				Derivative liabilities – commodity contracts:
		Fuel oils	$	1	$	—	$	—	$	1		$	—	$	—	$	—	$	—			Fuel oils	$	2	$	—	$	—	$	2		$	—	$	—	$	—	$	—
		Natural gas	—		11		3		14			—		6		3		9				Natural gas	—		13		3		16			—		6		3		9
		Power	17		—		—		17			57		—		2		59				Power	12		—		1		13			57		—		2		59

		Total Ameren Missouri	$	18	$	11	$	3	$	32		$	57	$	6	$	5	$	68			Total Ameren Missouri	$	14	$	13	$	4	$	31		$	57	$	6	$	5	$	68
Ameren Illinois	Ameren Illinois																				Ameren Illinois
		Derivative liabilities – commodity contracts:																				Derivative liabilities – commodity contracts:
		Natural gas	$	1	$	36	$	8	$	45		$	—	$	19	$	10	$	29			Natural gas	$	1	$	38	$	7	$	46		$	—	$	19	$	10	$	29
		Power	—		—		53		53			—		—		39		39				Power	—		—		68		68			—		—		39		39
		Total Ameren Illinois	$	1	$	36	$	61	$	98		$	—	$	19	$	49	$	68			Total Ameren Illinois	$	1	$	38	$	75	$	114		$	—	$	19	$	49	$	68
Ameren	Ameren																				Ameren
		Derivative liabilities – commodity contracts(b)	$	19	$	47	$	64	$	130		$	57	$	25	$	54	$	136			Derivative liabilities – commodity contracts(b)	$	15	$	51	$	79	$	145		$	57	$	25	$	54	$	136

(a)Balance excludes $5$6 million and $11 million of cash and cash equivalents, receivables, payables, and accrued income, net, for ~~March 31,~~June 30, 2023, and December 31, 2022, respectively.

(b)See the Ameren Missouri and Ameren Illinois sections of the table for a breakout of the fair value of Ameren’s derivative assets and liabilities by type of commodity.

(c)See the Ameren Missouri section of the table for a breakout of the fair value of Ameren’s nuclear decommissioning trust fund by investment type.

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Level 3 fuel oils, natural gas, and uranium derivative contract assets and liabilities measured at fair value on a recurring basis were immaterial for all periods presented. The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		2023						2022					2023								2022
		Ameren Missouri		Ameren Illinois		Ameren			Ameren Missouri		Ameren Illinois			Ameren			Ameren Missouri		Ameren Illinois			Ameren		Ameren Missouri		Ameren Illinois		Ameren
For the three months ended June 30:																For the three months ended June 30:
Beginning balance at April 1																Beginning balance at April 1	$	5	$	(52)		$	(47)	$	(53)	$	(74)	$	(127)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities																Realized and unrealized gains/(losses) included in regulatory assets/liabilities	14		(20)			(6)		(5)		32		27

Settlements																Settlements	(5)		4			(1)		22		(2)		20

For the three months ended March 31:
Ending balance at June 30																Ending balance at June 30	$	14	$	(68)		$	(54)	$	(36)	$	(44)	$	(80)
Change in unrealized gains/(losses) related to assets/liabilities held at June 30																Change in unrealized gains/(losses) related to assets/liabilities held at June 30	$	14	$	(20)		$	(6)	$	2	$	30	$	32
For the six months ended June 30:																For the six months ended June 30:
Beginning balance at January 1	Beginning balance at January 1	$	12	$	(33)	$	(21)		$	(15)	$	(117)		$	(132)	Beginning balance at January 1	$	12	$	(33)		$	(21)	$	(15)	$	(117)	$	(132)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities	Realized and unrealized gains/(losses) included in regulatory assets/liabilities	(6)		(20)		(26)			(41)		42			1		Realized and unrealized gains/(losses) included in regulatory assets/liabilities	8		(41)			(33)		(45)		74		29

Settlements	Settlements	(1)		1		—			3		1			4		Settlements	(6)		6			—		24		(1)		23

Ending balance at March 31		$	5	$	(52)	$	(47)		$	(53)	$	(74)		$	(127)
Change in unrealized gains/(losses) related to assets/liabilities held at March 31		$	(2)	$	(18)	$	(20)		$	(38)	$	42		$	4
Ending balance at June 30																Ending balance at June 30	$	14	$	(68)		$	(54)	$	(36)	$	(44)	$	(80)
Change in unrealized gains/(losses) related to assets/liabilities held at June 30																Change in unrealized gains/(losses) related to assets/liabilities held at June 30	$	14	$	(35)		$	(21)	$	(36)	$	72	$	36

All gains or losses related to our Level 3 derivative commodity contracts are expected to be recovered or returned through customer rates; therefore, there is no impact to either net income or other comprehensive income resulting from changes in the fair value of these instruments.

The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of ~~March 31,~~June 30, 2023, and December 31, 2022:


				Fair Value						Weighted Average(b)				Fair Value						Weighted Average(b)
		Commodity		Assets		Liabilities	Valuation Technique(s)	Unobservable Input(a)	Range			Commodity		Assets		Liabilities	Valuation Technique(s)	Unobservable Input(a)	Range
2023	2023	Power(c)	$	6	$	(53)	Discounted cash flow	Average forward peak and off-peak pricing – forwards/swaps ($/MWh)	22 – 74	46	2023	Power(c)	$	15	$	(69)	Discounted cash flow	Average forward peak and off-peak pricing – forwards/swaps ($/MWh)	32 – 67	43

								Nodal basis ($/MWh)	(9) – (1)	(4)								Nodal basis ($/MWh)	(9) – (1)	(5)

2022	2022	Power(d)	$	20	$	(41)	Discounted cash flow	Average forward peak and off-peak pricing – forwards/swaps ($/MWh)	38 – 89	51	2022	Power(d)	$	20	$	(41)	Discounted cash flow	Average forward peak and off-peak pricing – forwards/swaps ($/MWh)	38 – 89	51

								Nodal basis ($/MWh)	(10) – (1)	(4)								Nodal basis ($/MWh)	(10) – (1)	(4)

								Trend rate (%)	0 – 1	0								Trend rate (%)	0 – 1	0

(a)Generally, significant increases (decreases) in these inputs in isolation would result in a significantly higher (lower) fair value measurement.

(b)Unobservable inputs were weighted by relative fair value.

(c)Valuations use visible forward prices adjusted for nodal-to-hub basis differentials.

(d)Valuations through 2031 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2031 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials.

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The following table sets forth the carrying amount and, by level within the fair value hierarchy, the fair value of financial assets and liabilities disclosed, but not recorded, at fair value as of ~~March 31,~~June 30, 2023, and December 31, 2022:


		Carrying Amount			Fair Value												Carrying Amount			Fair Value
				Level 1			Level 2			Level 3			Total						Level 1			Level 2			Level 3			Total
				March 31, 2023															June 30, 2023
Ameren:	Ameren:															Ameren:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	237		$	237		$	—		$	—		$	237	Cash, cash equivalents, and restricted cash	$	246		$	246		$	—		$	—		$	246

Short-term debt	Short-term debt	1,248			—			1,248			—			1,248		Short-term debt	1,329			—			1,329			—			1,329
Long-term debt (including current portion)	Long-term debt (including current portion)	14,281		(a)	—			12,408			473		(b)	12,881		Long-term debt (including current portion)	14,678		(a)	—			12,745			453		(b)	13,198
Ameren Missouri:	Ameren Missouri:															Ameren Missouri:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	11		$	11		$	—		$	—		$	11	Cash, cash equivalents, and restricted cash	$	8		$	8		$	—		$	—		$	8

Short-term debt	Short-term debt	197			—			197			—			197		Short-term debt	373			—			373			—			373

Long-term debt (including current portion)	Long-term debt (including current portion)	6,341		(a)	—			5,706			—			5,706		Long-term debt (including current portion)	6,341		(a)	—			5,688			—			5,688
Ameren Illinois:	Ameren Illinois:															Ameren Illinois:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	217		$	217		$	—		$	—		$	217	Cash, cash equivalents, and restricted cash	$	229		$	229		$	—		$	—		$	229

Short-term debt	Short-term debt	324			—			324			—			324		Short-term debt	117			—			117			—			117

Long-term debt (including current portion)	Long-term debt (including current portion)	4,836		(a)	—			4,368			—			4,368		Long-term debt (including current portion)	5,232		(a)	—			4,735			—			4,735
		December 31, 2022															December 31, 2022
Ameren:	Ameren:															Ameren:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	216		$	216		$	—		$	—		$	216	Cash, cash equivalents, and restricted cash	$	216		$	216		$	—		$	—		$	216
Investment in industrial development revenue bonds(c)	Investment in industrial development revenue bonds(c)	240			—			240			—			240		Investment in industrial development revenue bonds(c)	240			—			240			—			240
Short-term debt	Short-term debt	1,070			—			1,070			—			1,070		Short-term debt	1,070			—			1,070			—			1,070
Long-term debt (including current portion)(c)	Long-term debt (including current portion)(c)	14,025		(a)	—			11,989			464		(b)	12,453		Long-term debt (including current portion)(c)	14,025		(a)	—			11,989			464		(b)	12,453
Ameren Missouri:	Ameren Missouri:															Ameren Missouri:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	13		$	13		$	—		$	—		$	13	Cash, cash equivalents, and restricted cash	$	13		$	13		$	—		$	—		$	13

Investment in industrial development revenue bonds(c)	Investment in industrial development revenue bonds(c)	240			—			240			—			240		Investment in industrial development revenue bonds(c)	240			—			240			—			240
Short-term debt	Short-term debt	329			—			329			—			329		Short-term debt	329			—			329			—			329
Long-term debt (including current portion)(c)	Long-term debt (including current portion)(c)	6,086		(a)	—			5,365			—			5,365		Long-term debt (including current portion)(c)	6,086		(a)	—			5,365			—			5,365
Ameren Illinois:	Ameren Illinois:															Ameren Illinois:
Cash, cash equivalents, and restricted cash	Cash, cash equivalents, and restricted cash	$	191		$	191		$	—		$	—		$	191	Cash, cash equivalents, and restricted cash	$	191		$	191		$	—		$	—		$	191
Short-term debt	Short-term debt	264			—			264			—			264		Short-term debt	264			—			264			—			264

Long-term debt (including current portion)	Long-term debt (including current portion)	4,835		(a)	—			4,320			—			4,320		Long-term debt (including current portion)	4,835		(a)	—			4,320			—			4,320

(a)Included unamortized debt issuance costs, which were excluded from the fair value measurement, of ~~$103~~$105 million, $45 million, and ~~$44~~$47 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of ~~March 31,~~June 30, 2023. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $99 million, $41 million, and $44 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2022.

(b)The Level 3 fair value amount consists of ATXI’s senior unsecured notes.

(c)Ameren and Ameren Missouri had an investment in industrial development revenue bonds, classified as held-to-maturity, ~~and recorded in “Other Assets,”~~ that were equal to the finance obligation for the Audrain CT energy center. As of December 31, 2022, the carrying amount of the investment in industrial development revenue bonds and the finance obligation approximated fair value.

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 arrangements, see Note 13 – Related-party Transactions and Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of the Form 10-K.

Support Services Agreements

Ameren Missouri and Ameren Illinois had long-term receivables included in “Other assets” from Ameren Services of ~~$36~~$33 million and ~~$39~~$35 million, respectively, as of ~~March 31,~~June 30, 2023, and $41 million and $43 million, respectively, as of December 31, 2022, 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 ~~March 31,~~June 30, 2023, and December 31, 2022:

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		March 31, 2023				December 31, 2022					June 30, 2023				December 31, 2022
		Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois			Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois
Income taxes payable to parent(a)	Income taxes payable to parent(a)	$	—	$	80	$	—	$	50	Income taxes payable to parent(a)	$	—	$	28	$	—	$	50
Income taxes receivable from parent(b)	Income taxes receivable from parent(b)	54		—		39		—		Income taxes receivable from parent(b)	38		—		39		—

(a)Included in “Accounts payable – affiliates” on the balance sheet.

(b)Included in “Accounts receivable – affiliates” on the balance sheet.

Effects of Related-party Transactions on the Statement of Income

The following table presents the impact on Ameren Missouri and Ameren Illinois of related-party transactions for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


				Three Months							Three Months				Six Months
Agreement	Agreement	Income Statement Line Item				Ameren Missouri		Ameren Illinois	Agreement	Income Statement Line Item			Ameren Missouri		Ameren Illinois		Ameren Missouri		Ameren Illinois
Ameren Missouri power supply	Ameren Missouri power supply	Operating Revenues	2023		$	(b)	$	(a)	Ameren Missouri power supply	Operating Revenues	2023	$	(b)	$	(a)	$	(b)	$	(a)
agreements with Ameren Illinois	agreements with Ameren Illinois		2022			4		(a)	agreements with Ameren Illinois		2022		1		(a)		5		(a)
Ameren Missouri and Ameren Illinois	Ameren Missouri and Ameren Illinois	Operating Revenues	2023		$	10	$	(b)	Ameren Missouri and Ameren Illinois	Operating Revenues	2023	$	8	$	(b)	$	18	$	(b)
rent and facility services	rent and facility services		2022			6		(b)	rent and facility services		2022		6		(b)		12		(b)
Ameren Missouri and Ameren Illinois miscellaneous	Ameren Missouri and Ameren Illinois miscellaneous	Operating Revenues	2023		$	(b)	$	(b)	Ameren Missouri and Ameren Illinois miscellaneous	Operating Revenues	2023	$	(b)	$	(b)	$	(b)	$	(b)
support services	support services		2022			(b)		1	support services		2022		(b)		(b)		(b)		1
Total Operating Revenues	Total Operating Revenues		2023		$	10	$	(b)	Total Operating Revenues		2023	$	8	$	(b)	$	18	$	(b)
			2022			10		1			2022		7		(b)		17		1
Ameren Illinois power supply	Ameren Illinois power supply	Purchased Power	2023		$	(a)	$	(b)	Ameren Illinois power supply	Purchased Power	2023	$	(a)	$	(b)	$	(a)	$	(b)
agreements with Ameren Missouri	agreements with Ameren Missouri		2022			(a)		4	agreements with Ameren Missouri		2022		(a)		1		(a)		5
Ameren Missouri and Ameren Illinois	Ameren Missouri and Ameren Illinois	Purchased Power	2023		$	(b)	$	(b)	Ameren Missouri and Ameren Illinois	Purchased Power	2023	$	1	$	(b)	$	1	$	(b)
transmission services from ATXI	transmission services from ATXI		2022			(b)		(b)	transmission services from ATXI		2022		(b)		(b)		(b)		(b)
Total Purchased Power	Total Purchased Power		2023		$	(b)	$	(b)	Total Purchased Power		2023	$	1	$	(b)	$	1	$	(b)
			2022			(b)		4			2022		(b)		1		(b)		5
Ameren Missouri and Ameren Illinois	Ameren Missouri and Ameren Illinois	Other Operations and Maintenance	2023		$	(b)	$	2	Ameren Missouri and Ameren Illinois	Other Operations and Maintenance	2023	$	(b)	$	(b)	$	(b)	$	2
rent and facility services	rent and facility services		2022			(b)		1	rent and facility services		2022		(b)		(b)		(b)		1
Ameren Services support services	Ameren Services support services	Other Operations and Maintenance	2023		$	35	$	35	Ameren Services support services	Other Operations and Maintenance	2023	$	35	$	33	$	70	$	68
agreement	agreement		2022			38		35	agreement		2022		33		32		71		67
Total Other Operations and	Total Other Operations and		2023		$	35	$	37	Total Other Operations and		2023	$	35	$	33	$	70	$	70
Maintenance	Maintenance		2022			38		36	Maintenance		2022		33		32		71		68
Money pool borrowings (advances)	Money pool borrowings (advances)	(Interest Charges)/Other Income, Net	2023		$	(b)	$	(b)	Money pool borrowings (advances)	(Interest Charges)/Other Income, Net	2023	$	(b)	$	(b)	$	(b)	$	(b)
			2022			(b)		(b)			2022		(b)		(b)		(b)		(b)

(a)Not applicable.

(b)Amount less than $1 million.

NOTE 9 – COMMITMENTS AND CONTINGENCIES

We are involved in legal, tax, and regulatory proceedings before various courts, regulatory commissions, authorities, and governmental agencies with respect to matters that arise in the ordinary course of business, some of which involve substantial amounts of money. We believe that the final disposition of these proceedings, except as otherwise disclosed in the notes to our financial statements in this report and in the Form 10-K, will not have a material adverse effect on our results of operations, financial position, or liquidity.

Reference is made to Note 1 – Summary of Significant Accounting Policies, Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, Note 13 – Related-party Transactions, and Note 14 – Commitments and Contingencies under Part II, Item 8, of the Form 10-K. See also Note 1 – Summary of Significant Accounting Policies, Note 2 – Rate and Regulatory Matters, Note 8 – Related-party Transactions, and Note 10 – Callaway Energy Center of this report.

Environmental Matters

Our electric generation, transmission, and distribution and natural gas distribution and storage operations must comply with a variety of statutes and regulations relating to the protection of the environment and human health and safety including permitting programs implemented by federal, state, and local authorities. Such environmental laws address air emissions; discharges to water bodies; the storage, handling and disposal of hazardous substances and waste materials; siting and land use requirements; and potential ecological impacts. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing, or modified ~~facilities.~~energy-

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related facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures. We employ dedicated personnel knowledgeable in environmental matters to oversee our business activities’ compliance with ~~regulatory~~ requirements of environmental laws.

Environmental regulations have a significant impact on the electric utility industry and compliance with these regulations could be costly for Ameren Missouri, which operates coal-fired power plants. Regulations under the Clean Air Act that apply to the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO2, particulate matter, NOx, mercury, toxic metals and acid gases, and CO2 emissions. Regulations implementing the Clean Water Act govern both intake and discharges of water, as well as evaluation of the ecological and biological impact of our operations, and could require modifications to water intake structures or more stringent limitations on wastewater discharges. Depending upon the scope of modifications ultimately required by state regulators, capital expenditures associated with these modifications could be significant. The management and disposal of coal ash is regulated under the Resource Conservation and Recovery Act and the CCR Rule, which require the closure of surface impoundments at Ameren Missouri’s coal-fired energy centers. The individual or combined effects of compliance with existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of operations at some of Ameren Missouri’s energy centers. Ameren and Ameren Missouri expect that such compliance costs would be recoverable through rates, subject to MoPSC prudence review, but the timing of costs and their recovery could be subject to regulatory lag.

Additionally, Ameren Missouri’s wind generation facilities may be subject to operating restrictions to limit the impact on protected species. From April through October, ~~in both~~since 2021, ~~and 2022,~~ Ameren ~~Missouri's~~Missouri’s High Prairie Renewable Energy Center curtailed nighttime operations to limit impacts on protected species. Seasonal nighttime curtailment began again in April 2023 as the critical biological season resumed, but the extent and duration of the curtailment is unknown at this time as assessment of mitigation technologies is ongoing. Ameren Missouri does not anticipate these operating curtailments to have a material impact on its results of operations, financial position, or liquidity.

Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $90 million to $120 million from 2023 through 2027 in order to comply with existing environmental regulations. Additional capital expenditures for environmental controls beyond 2027 could be required. This estimate of capital expenditures includes surface impoundment closure and corrective action measures required by the CCR Rule and potential modifications to cooling water intake structures at existing power plants under Clean Water Act rules, all of which are discussed below. In addition to planned retirements of coal-fired energy centers as set forth in the 2022 Change to the 2020 IRP filed with the MoPSC in June 2022 and as noted in the NSR and Clean Air Act litigation discussed below and Illinois emissions standards discussed ~~below,~~in Note 14 – Commitments and Contingencies under Part II, Item 8, of the Form 10-K, Ameren Missouri’s current plan for compliance with existing air emission regulations includes burning low-sulfur coal and installing new or optimizing existing air pollution control equipment. The actual amount of capital expenditures required to comply with existing environmental regulations may vary substantially from the above estimates because of uncertainty as to future permitting requirements by state regulators and the EPA, revisions to regulatory obligations, and varying cost of potential compliance strategies, among other things.

The following sections describe the more significant environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. The EPA periodically amends and revises its regulations and proposes amendments to regulations and guidelines, which could ultimately result in the revision of all or part of such rules.

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. ~~The CSAPR is implemented through a series of phases, and the second phase became effective in 2017.~~ In April 2022, the EPA proposed plans for additional NOx emission reductions from power plants in Missouri, Illinois, and other states through revisions to the CSAPR. In January 2023, the EPA issued its final disapproval of Missouri’s proposed state implementation plan for addressing the transport of ozone under the Good Neighbor Plan of the Clean Air Act. The disapproval of the state plan allows the EPA to implement revisions to the CSAPR through a federal implementation plan. In March 2023, the EPA announced federal implementation plan requirements, which were subsequently published to the Federal Register in June 2023, reducing the amount of NOx allowances available for state budgets and imposing NOx emission limits on electric generating units for Missouri, Illinois, and other states under the Good Neighbor Plan of the Clean Air Act. In April 2023, the Missouri Attorney General and Ameren Missouri separately filed lawsuits in the ~~Eighth Circuit~~United States Court of Appeals for the Eighth Circuit challenging the EPA’s disapproval of the Missouri state plan and sought a stay of the EPA’s disapproval of the Missouri state plan. ~~Unless stayed by a judicial action,~~The United States Court of Appeals for the Eighth Circuit in ~~mid-2023,~~May 2023 granted those stay motions thereby preventing the EPA ~~is expected to finalize a~~from imposing the federal implementation plan ~~reducing~~until the ~~amount~~court of NOx ~~allowances available for state budgets and imposing NO~~x ~~emission limits on electric generating units.~~appeals issues a ruling, which is expected in 2024. Ameren Missouri has complied with the current CSAPR requirements by minimizing emissions through the use of low-sulfur coal, operation of two scrubbers at its Sioux Energy Center, and optimization of other existing NOx air pollution control equipment. Restrictions on the use of state budget NOx allowances for compliance with NOx emission limits could result in additional controls being required on Ameren Missouri’s generating units and/or the reduction of operations. ~~Ameren Missouri is evaluating potential options to comply with the federal implementation plan.~~ Any additional costs for compliance are expected to be recovered from customers, subject to MoPSC prudence review, through the FAC or higher base rates.

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CO2 Emissions Standards

In June 2022, the United States Supreme Court issued its decision in West Virginia v. EPA,, clarifying that there are limits on how the EPA may regulate greenhouse gases absent further direction from the United States Congress. The court concluded that ~~emission caps~~the EPA’s proposed rules were designed to shift generation from fossil-fuel-fired power plants to renewable energy facilities, ~~would require~~which was improper absent specific congressional ~~authorization and~~authorization. In May 2023, the EPA issued a proposed rule that ~~such authorization had not been given under the Clean Air Act. The decision by the United States Supreme Court may affect the EPA’s development of any new regulations to address~~would set CO2 ~~emissions from coal-~~emission standards for new and existing fossil-fuel-fired power plants based on the adoption of carbon capture technology, natural gas co-firing, and co-firing hydrogen fuel to reduce emissions. If the proposed rule were adopted, the affected fossil-fuel-fired power plants would be required to comply with the rule through a phased-in approach or retire. Capacity restrictions for coal-fired units could apply as early as 2030. Larger natural gas-fired power ~~plants; however, at this time,~~plants would be required to co-fire with hydrogen by 2032, with additional requirements by 2038. The EPA expects to issue a final rule in 2024. Legal challenges to the final rule, if adopted, are expected. Ameren Missouri cannot predict the results of any such challenges. Ameren Missouri is currently reviewing the proposed rule and cannot predict the impact of any such regulations ~~or the decision by the United States Supreme Court~~ on the results of operations, financial position, and liquidity of Ameren or Ameren Missouri.

NSR and Clean Air Act Litigation

In January 2011, the United States Department of Justice, on behalf of the EPA, filed a complaint against Ameren Missouri in the United States District Court for the Eastern District of Missouri alleging that projects performed in 2007 and 2010 at the coal-fired Rush Island Energy Center violated provisions of the Clean Air Act and Missouri law. In January 2017, the district court issued a liability ruling against Ameren Missouri and, in September 2019, entered a remedy order that required Ameren Missouri to install a flue gas desulfurization system at the Rush Island Energy Center and a dry sorbent injection system at the Labadie Energy Center. Following an appeal from Ameren Missouri in August 2021, the United States Court of Appeals for the Eighth Circuit affirmed the liability ruling and the district court’s remedy order as it related to the installation of a flue gas desulfurization system at the Rush Island Energy Center, but reversed the order as it related to the installation of a dry sorbent injection system at the Labadie Energy Center. In November 2021, the court of appeals issued an order denying requests for re-consideration sought by both Ameren Missouri and the United States Department of Justice.

Based on its assessment of available legal, operational, and regulatory alternatives, Ameren Missouri filed a motion in December 2021, with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The March ~~31,~~30, 2024 compliance date contained in the district court’s September 2019 remedy order remains in effect unless extended by the district court. In 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISO, and design and procurement activities necessary to complete the upgrades are underway. Ameren Missouri expects to complete the upgrades by mid-2025. In 2022, the FERC approvedRush Island Energy Center began operating as a system support resource ~~agreement, which became effective as of~~on September 1, 2022. ~~The~~In 2023, the MISO extended the system support resource designation for the Rush Island Energy Center through August 2024, and in July 2023, an agreement between Ameren Missouri and the MISO was filed with the FERC for approval that details the manner of continued operation for ~~a system support resource~~the Rush Island Energy Center that results in operating during peak demand times and emergencies. The system support resource designation and the related agreement are subject to annual renewal and revision. The FERC is under no deadline to issue an order. The transmission upgrade projects have been approved by the MISO, and construction activities necessary to complete the upgrades are underway. Ameren Missouri expects to complete the last of the upgrades by mid-2025. In ~~September 2022,~~August 2023, Ameren Missouri requested the district court to extend the March 30, 2024 compliance date to October 15, 2024, at which point Ameren Missouri proposes to retire the Rush Island Energy ~~Center began operating consistent with the system support resource agreement.~~Center. In addition, in October 2022, the FERC established hearing and settlement procedures in response to an August 2022 request from Ameren Missouri for recovery of non-energy costs under the related MISO tariff. In May 2023, a settlement agreement between Ameren Missouri and certain intervenors in the non-energy costs proceeding at the FERC, which provides for recovery of substantially all of Ameren Missouri’s requested non-energy costs through August 2023, was filed with the FERC for approval. The FERC is under no deadline to issue an ~~order related to this proceeding.~~order. Revenues and costs under the MISO tariff are included in the FAC. The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISO determination of the Rush Island Energy Center as a system support resource or the FERC’s approval. The district court is under no deadline to issue a ruling modifying the remedy order. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review the planned accelerated retirement of the Rush Island Energy Center. See Note 2 – Rate and Regulatory Matters for additional information.

In connection with the planned accelerated retirement of the Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to Missouri’s securitization statute. As of ~~March 31,~~June 30, 2023, the Rush Island Energy Center had a net plant balance of approximately ~~$0.6 billion~~$550 million included in plant to be abandoned, net, within “Property, Plant, and Equipment, Net” and a rate base of approximately ~~$0.4~~$0.5 billion. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of the Form 10-K for additional information regarding plant to be abandoned, net.

Ameren Missouri is unable to predict the ultimate resolution of this matter; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri.

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Clean Water Act

The EPA’s regulations implementing Section 316(b) of the Clean Water Act require power plant operators to evaluate cooling water intake structures and identify measures for reducing the number of aquatic organisms impinged on a power plant’s cooling water intake screens or entrained through the plant’s cooling water system. All of Ameren Missouri’s coal-fired and nuclear energy centers are subject to the cooling water intake structures rule. Requirements of the rule are implemented by state regulators through the permit renewal process of each power plant’s water discharge permit. Permits for Ameren Missouri’s coal-fired and nuclear energy centers have been issued or are in the process of renewal.

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In 2015, the EPA issued a rule to revise the effluent limitation guidelines applicable to steam electric generating units. These guidelines established national standards for water discharges, prohibit effluent discharges of certain waste streams, and impose more stringent limitations on certain water discharges from power plants by 2025. To comply with these guidelines, Ameren Missouri installed dry ash handling systems and wastewater treatment facilities at its coal-fired energy centers.

CCR Management

The EPA’s 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. Ameren Missouri plans to substantially complete the closures of the remaining surface impoundments at its Sioux Energy Center and retired Meramec Energy Center as required by the CCR Rule by the end of 2024. Ameren Missouri’s CCR management compliance plan includes installation of groundwater monitoring equipment and groundwater treatment facilities. Ameren and Ameren Missouri have AROs of ~~$48~~$45 million recorded on their respective balance sheets as of ~~March 31,~~June 30, 2023, associated with CCR storage facilities.

Remediation

The Ameren Companies are involved in a number of remediation actions to clean up sites impacted by the use or disposal of materials containing hazardous substances. Federal and state laws can require responsible parties to fund remediation regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site.

As of ~~March 31,~~June 30, 2023, Ameren Illinois has remediated the majority of the 44 former MGP sites in Illinois and could substantially conclude remediation efforts at the remaining sites in 2023. The ICC allows Ameren Illinois to recover such remediation and related litigation costs from its electric and natural gas utility customers through environmental cost riders that are subject to annual prudence reviews by the ICC. As of ~~March 31,~~June 30, 2023, Ameren Illinois estimated the remaining obligation related to these former MGP sites at ~~$58~~$61 million to ~~$108~~$112 million. Ameren and Ameren Illinois recorded a liability of ~~$58~~$61 million to represent the estimated minimum obligation for these sites, as no other amount within the range was a better estimate. About half of the remaining liability recorded relates to remediation activities that are expected to be completed after 2023.

The scope of the remediation activities at these former MGP sites may increase as remediation efforts continue. Considerable uncertainty remains in these estimates because many site-specific factors can influence the actual costs, including unanticipated underground structures, the degree to which groundwater is encountered, regulatory changes, local ordinances, and site accessibility. The actual costs and timing of completion may vary substantially from these estimates.

Our operations or those of our predecessor companies involve the use of, disposal of, and, in appropriate circumstances, the cleanup of substances regulated under environmental laws. We are unable to determine whether such historical practices will result in future environmental commitments, including additional or more stringent cleanup standards, or 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. Annual decommissioning costs of $7 million are included in the costs used to establish electric rates for Ameren Missouri’s customers. Every three years, the MoPSC requires Ameren Missouri to file an updated cost study and funding analysis for decommissioning its Callaway Energy Center. An updated cost study and funding analysis was filed with the MoPSC in November 2020 and reflected within the ARO. In February 2021, the MoPSC approved no change in electric rates for decommissioning costs based on Ameren Missouri’s updated cost study funding analysis. See Note 13 – Supplemental Information for more information on Ameren Missouri’s AROs.

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Insurance

The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at ~~April 1,~~June 30, 2023:


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, 2023	$	450		$	—
Pool participation	(a)	13,210		(a)	138		(b)
		$	13,660	(c)	$	138
Property damage:
NEIL and EMANI	April 1, 2023	$	3,200	(d)	$	28	(e)
Accidental outage:
NEIL	April 1, 2023	$	490	(f)	$	9	(e)

(a)Provided through mandatory participation in an industrywide retrospective premium assessment program. The maximum coverage available is dependent on the number of United States commercial reactors participating in the program.

(b)Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $450 million in the event of an incident at any licensed United States commercial reactor, payable at $21 million per year.

(c)Limit of liability for each incident under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended. This limit is subject to change to account for the effects of inflation and changes in the number of licensed power reactors.

(d)NEIL provides $2.7 billion in property damage, stabilization, decontamination, and premature decommissioning insurance for radiation events and $2.3 billion in property damage insurance for nonradiation events. EMANI provides $490 million in property damage insurance for both radiation and nonradiation events.

(e)All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL.

(f)Accidental outage insurance provides for lost sales in the event of a prolonged accidental outage. Weekly indemnity up to $4.5 million for 52 weeks, which commences after the first 12 weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter for a total not exceeding the policy limit of $490 million. Nonradiation events are limited to $328 million.

The Price-Anderson Act is a federal law that limits the liability for claims from an incident involving any licensed United States commercial nuclear energy center. The limit is based on the number of licensed reactors. The limit of liability and the maximum potential annual payments are adjusted at least every five years for inflation to reflect changes in the Consumer Price Index. The most recent five-year inflationary adjustment became effective in November 2018. Owners of a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by the Price-Anderson Act.

Losses resulting from terrorist attacks on nuclear facilities insured by NEIL are subject to industrywide aggregates, such that terrorist acts against one or more commercial nuclear power plants within a stated time period would be treated as a single event, and the owners of the nuclear power plants would share the limit of liability. NEIL policies have an aggregate limit of $3.2 billion within a 12-month period for radiation events, or $1.8 billion for events not involving radiation contamination, resulting from terrorist attacks. The EMANI policies are not subject to industrywide aggregates in the event of terrorist attacks on nuclear facilities.

If losses from a nuclear incident at the Callaway Energy Center exceed insurance limits, are not covered by insurance, or if coverage is unavailable, Ameren Missouri is at risk for any uninsured losses. If a serious nuclear incident were to occur, it could have a material adverse effect on Ameren’s and Ameren Missouri’s results of operations, financial position, or liquidity.

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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 six months ended ~~March 31,~~June 30, 2023 and 2022:


			Pension Benefits						Postretirement Benefits					Pension Benefits									Postretirement Benefits
		Three Months					Three Months	Three Months						Six Months						Three Months			Six Months
			2023		2022				2023		2022			2023		2022		2023			2022		2023		2022		2023		2022
Service cost(a)	Service cost(a)		$	23	$	33			$	3	$	5	Service cost(a)	$	23	$	31	$	46		$	64	$	3	$	5	$	6	$	10
Non-service cost components:	Non-service cost components:												Non-service cost components:
Interest cost	Interest cost		55		40				11		8		Interest cost	56		41		111			81		12		9		23		17
Expected return on plan assets(b)	Expected return on plan assets(b)		(83)		(80)				(23)		(21)		Expected return on plan assets(b)	(84)		(80)		(167)			(160)		(23)		(22)		(46)		(43)
Amortization of(b):	Amortization of(b):												Amortization of(b):

Prior service benefit	Prior service benefit		—		—				(1)		(1)		Prior service benefit	—		—		—			—		(1)		(1)		(2)		(2)
Actuarial loss (gain)	Actuarial loss (gain)		(29)		6				(11)		(4)		Actuarial loss (gain)	(28)		6		(57)			12		(12)		(5)		(23)		(9)
Total non-service cost components(c)	Total non-service cost components(c)		$	(57)	$	(34)			$	(24)	$	(18)	Total non-service cost components(c)	$	(56)	$	(33)	$	(113)		$	(67)	$	(24)	$	(19)	$	(48)	$	(37)

Net periodic benefit income(d)	Net periodic benefit income(d)		$	(34)	$	(1)			$	(21)	$	(13)	Net periodic benefit income(d)	$	(33)	$	(2)	$	(67)		$	(3)	$	(21)	$	(14)	$	(42)	$	(27)

(a)Service cost, net of capitalization, is reflected in “Operating Expenses – Other operations and maintenance” on Ameren’s statement of income.

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(b)Prior service benefit is amortized on a straight-line basis over the average future service of active participants benefiting under a plan amendment. Net actuarial gains or losses related to the net benefit obligation subject to amortization are amortized on a straight-line basis over 10 years. The difference between the actual and expected return on plan assets is amortized over 4 years.

(c)Non-service cost components are reflected in “Other Income, Net” on Ameren’s consolidated statement of income. See Note 5 – Other Income, Net for additional information.

(d)Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) incurred by Ameren Missouri under GAAP and the level of such costs included in rates.

Ameren Missouri and Ameren Illinois are responsible for their respective share of Ameren’s pension and other postretirement costs. The following table presents the respective share of net periodic pension and other postretirement benefit costs (income) incurred for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


			Pension Benefits						Postretirement Benefits					Pension Benefits									Postretirement Benefits
		Three Months					Three Months	Three Months						Six Months						Three Months			Six Months
			2023		2022				2023		2022			2023		2022		2023			2022		2023		2022		2023		2022
Ameren Missouri(a)	Ameren Missouri(a)		$	(18)	$	(1)			$	(8)	$	(3)	Ameren Missouri(a)	$	(17)	$	(1)	$	(35)		$	(2)	$	(7)	$	(4)	$	(15)	$	(7)
Ameren Illinois	Ameren Illinois		(14)		1				(13)		(10)		Ameren Illinois	(13)		—		(27)			1		(14)		(10)		(27)		(20)
Other	Other		(2)		(1)				—		—		Other	(3)		(1)		(5)			(2)		—		—		—		—
Ameren(a)	Ameren(a)		$	(34)	$	(1)			$	(21)	$	(13)	Ameren(a)	$	(33)	$	(2)	$	(67)		$	(3)	$	(21)	$	(14)	$	(42)	$	(27)

(a)Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs (income) incurred by Ameren Missouri under GAAP and the level of such costs included in rates.

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NOTE 12 – INCOME TAXES

The following table presents a reconciliation of the federal statutory corporate income tax rate to the effective income tax rate for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Ameren				Ameren Missouri				Ameren Illinois
		2023		2022		2023		2022		2023		2022

															Ameren				Ameren Missouri				Ameren Illinois
															2023		2022		2023		2022		2023		2022
Three Months	Three Months													Three Months
Federal statutory corporate income tax rate	Federal statutory corporate income tax rate	21	%	21	%	21	%	21	%	21	%	21	%	Federal statutory corporate income tax rate	21	%	21	%	21	%	21	%	21	%	21	%
Increases (decreases) from:	Increases (decreases) from:													Increases (decreases) from:
Amortization of deferred investment tax credit	Amortization of deferred investment tax credit	—		—		—		(1)		—		—		Amortization of deferred investment tax credit	—		—		—		(1)		—		—
Amortization of excess deferred taxes(a)	Amortization of excess deferred taxes(a)	(8)		(8)		(16)		(16)		(2)		(2)		Amortization of excess deferred taxes(a)	(7)		(8)		(15)		(15)		(2)		(2)

Depreciation differences														Depreciation differences	—		—		—		—		(1)		(1)
Other														Other	—		1		—		—		—		—
Renewable and other tax credits(b)	Renewable and other tax credits(b)	(5)		(5)		(10)		(11)		—		—		Renewable and other tax credits(b)	(5)		(4)		(10)		(10)		—		—
State tax	State tax	6		5		4		3		7		7		State tax	5		5		3		3		7		7
Stock-based compensation		(1)		(1)		—		—		—		—

Effective income tax rate														Effective income tax rate	14	%	15	%	(1)	%	(2)	%	25	%	25	%
Six Months														Six Months
Federal statutory corporate income tax rate														Federal statutory corporate income tax rate	21	%	21	%	21	%	21	%	21	%	21	%
Increases (decreases) from:														Increases (decreases) from:
Amortization of deferred investment tax credit														Amortization of deferred investment tax credit	—		—		—		(1)		—		—
Amortization of excess deferred taxes(a)														Amortization of excess deferred taxes(a)	(8)		(8)		(15)		(16)		(2)		(2)
Depreciation differences														Depreciation differences	—		—		—		—		(1)		—
Renewable and other tax credits(b)														Renewable and other tax credits(b)	(4)		(5)		(10)		(10)		—		—
State tax														State tax	5		5		3		3		7		7

Other permanent items	Other permanent items	(1)		—		(3)		—		(1)		—		Other permanent items	(1)		—		—		—		—		—
Effective income tax rate	Effective income tax rate	12	%	12	%	(4)	%	(4)	%	25	%	26	%	Effective income tax rate	13	%	13	%	(1)	%	(3)	%	25	%	26	%

(a)Reflects the amortization of amounts resulting from the revaluation of deferred income taxes subject to regulatory ratemaking, which are being refunded to customers. Deferred income taxes are revalued when federal or state income tax rates change, and the offset to the revaluation of deferred income taxes subject to regulatory ratemaking is recorded to a regulatory asset or liability.

(b)The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM.

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 ~~March 31,~~June 30, 2023, and December 31, 2022:


		March 31, 2023						December 31, 2022							June 30, 2023						December 31, 2022
		Ameren		Ameren Missouri		Ameren Illinois		Ameren		Ameren Missouri		Ameren Illinois			Ameren		Ameren Missouri		Ameren Illinois		Ameren		Ameren Missouri		Ameren Illinois
“Cash and cash equivalents”	“Cash and cash equivalents”	$	10	$	3	$	—	$	10	$	—	$	—	“Cash and cash equivalents”	$	7	$	—	$	—	$	10	$	—	$	—

Restricted cash included in “Other current assets”	Restricted cash included in “Other current assets”	13		5		6		13		5		6		Restricted cash included in “Other current assets”	13		5		6		13		5		6
Restricted cash included in “Other assets”	Restricted cash included in “Other assets”	211		—		211		185		—		185		Restricted cash included in “Other assets”	223		—		223		185		—		185
Restricted cash included in “Nuclear decommissioning trust fund”	Restricted cash included in “Nuclear decommissioning trust fund”	3		3		—		8		8		—		Restricted cash included in “Nuclear decommissioning trust fund”	3		3		—		8		8		—
Total cash, cash equivalents, and restricted cash	Total cash, cash equivalents, and restricted cash	$	237	$	11	$	217	$	216	$	13	$	191	Total cash, cash equivalents, and restricted cash	$	246	$	8	$	229	$	216	$	13	$	191

Restricted cash included in “Other current assets” primarily represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees. Restricted cash included in “Other assets” on Ameren’s

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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 ~~March 31,~~June 30, 2023, and December 31, 2022, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of ~~$35~~$37 million and $31 million, respectively.

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The following table provides a reconciliation of the beginning and ending amount of the allowance for doubtful accounts for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months			Three Months						Six Months
			2023			2022			2023		2022		2023		2022
Ameren:	Ameren:							Ameren:
Beginning of period	Beginning of period		$	31		$	29	Beginning of period	$	34	$	28	$	31	$	29
Bad debt expense	Bad debt expense		10			4		Bad debt expense	13		6		23		9
Charged to other accounts(a)								Charged to other accounts(a)	1		1		1		2
Net write-offs	Net write-offs		(7)			(5)		Net write-offs	(9)		(5)		(16)		(10)
End of period	End of period		$	34		$	28	End of period	$	39	$	30	$	39	$	30
Ameren Missouri:	Ameren Missouri:							Ameren Missouri:
Beginning of period	Beginning of period		$	13		$	13	Beginning of period	$	12	$	11	$	13	$	13
Bad debt expense	Bad debt expense		2			1		Bad debt expense	2		2		4		3
Net write-offs	Net write-offs		(3)			(3)		Net write-offs	(2)		(1)		(5)		(4)
End of period	End of period		$	12		$	11	End of period	$	12	$	12	$	12	$	12
Ameren Illinois:(a)
Ameren Illinois:(b)								Ameren Illinois:(b)
Beginning of period	Beginning of period		$	18		$	16	Beginning of period	$	22	$	17	$	18	$	16
Bad debt expense	Bad debt expense		8			3		Bad debt expense	11		4		19		6
Charged to other accounts(a)								Charged to other accounts(a)	1		1		1		2
Net write-offs	Net write-offs		(4)			(2)		Net write-offs	(7)		(4)		(11)		(6)
End of period	End of period		$	22		$	17	End of period	$	27	$	18	$	27	$	18

(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~~riders 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.

As of ~~March 31,~~June 30, 2023, accounts receivable balances that were 30 days or greater past due or that were a part of a deferred payment arrangement represented ~~23%~~26%, 15%, and ~~28%~~35%, or ~~$153~~$133 million, ~~$33~~$28 million, and ~~$120~~$106 million, of Ameren’s, Ameren Missouri’s, and Ameren Illinois’ customer trade receivables before allowance for doubtful accounts, respectively. In comparison, as of ~~March 31,~~June 30, 2022, these percentages were ~~20%~~19%, ~~15%~~14%, and ~~23%~~24%, or ~~$116~~$107 million, ~~$31~~$29 million, and ~~$85~~$78 million, for Ameren, Ameren Missouri, and Ameren Illinois, respectively.

Supplemental Cash Flow Information

The following table provides noncash financing and investing activity excluded from the statements of cash flows for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022:

March 31, 2023 March 31, 2022
Ameren Ameren
Missouri Ameren
Illinois Ameren Ameren
Missouri Ameren
Illinois
Investing:
Accrued capital expenditures $ 298 $ 153 $ 138 $ 345 $ 194 $ 147
Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund 54 54 — (71) (71) —
Return of investment in industrial development revenue bonds(a)
240 240 — — — —
Financing:
Issuance of common stock for stock-based compensation $ 37 $ — $ — $ 31 $ — $ —
Issuance of common stock under the DRPlus 7 — — 8 — —
Termination of a financing obligation(a)
240 240 — — — —

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	June 30, 2023						June 30, 2022
	Ameren		Ameren Missouri				Ameren Illinois	Ameren		Ameren Missouri		Ameren Illinois
Investing:
Accrued capital expenditures	$	325	$	132	$	173		$	408	$	204	$	193

Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund	105		105		—			(211)		(211)		—
Return of investment in industrial development revenue bonds(a)	240		240		—			—		—		—
Financing:
Issuance of common stock for stock-based compensation	$	37	$	—	$	—		$	31	$	—	$	—
Issuance of common stock under the DRPlus	7		—		—			8		—		—
Termination of a financing obligation(a)	240		240		—			—		—		—

(a)In January 2023, Ameren Missouri and Audrain County mutually agreed to terminate a financing obligation agreement related to the CT energy center in Audrain County, which was scheduled to expire in December 2023. No cash was exchanged in connection with the termination of the agreement as the $240 million principal amount of the financing obligation due from Ameren Missouri was equal to the amount of bond service payments due to Ameren Missouri.

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Asset Retirement Obligations

The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the ~~three~~six months ended ~~March 31,~~June 30, 2023:


		Ameren Missouri			Ameren Illinois			Ameren				Ameren Missouri			Ameren Illinois			Ameren
Balance at December 31, 2022	Balance at December 31, 2022	$	782	(a)	$	4	(b)	$	786	(a)	Balance at December 31, 2022	$	782	(a)	$	4	(b)	$	786	(a)

Liabilities settled	Liabilities settled	(2)			—			(2)			Liabilities settled	(4)			—			(4)
Accretion	Accretion	8		(c)	—			8		(c)	Accretion	16		(c)	—			16		(c)

Balance at March 31, 2023		$	788	(a)	$	4	(b)	$	792	(a)
Balance at June 30, 2023											Balance at June 30, 2023	$	794	(a)	$	4	(b)	$	798	(a)

(a)Balance included $23 million in “Other current liabilities” on the balance sheet as of both ~~March 31,~~June 30, 2023, and December 31, 2022.

(b)Included in “Other deferred credits and liabilities” on the balance sheet.

(c)Accretion expense attributable to Ameren Missouri was recorded as a decrease to regulatory liabilities.

Stock-based Compensation

In the first quarter of 2023, Ameren granted 265,422 performance share units with a grant date fair value of $24 million and 116,701 restricted share units with a grant date fair value of $10 million. Awards vest approximately 3 years after the grant date or on a pro-rata basis upon death or eligible retirement. The performance share units vest based on the achievement of certain specified market performance measures (227,494 performance share units) or clean energy transition targets (37,928 performance share units). The exact number of shares issued pursuant to a performance share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the performance goals.

For the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022, excess tax benefits associated with the settlement of stock-based compensation awards reduced income tax expense by $6 million and $5 million, respectively.

Deferred Compensation

At ~~March 31,~~June 30, 2023, and December 31, 2022, the present value of benefits to be paid for deferred compensation obligations was $85 million and $87 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet.

Operating Revenues

As of ~~March 31,~~June 30, 2023 and 2022, our remaining performance obligations for contracts with a term greater than one year were immaterial. The Ameren Companies elected not to disclose the aggregate amount of the transaction price allocated to the performance obligations that are unsatisfied as of the end of the reporting period for contracts with an initial expected term of one year or less.

See Note 14 – Segment Information for disaggregated revenue information.

Excise Taxes

Ameren Missouri and Ameren Illinois collect from their customers excise taxes, including municipal and state excise taxes and gross receipts taxes that are levied on the sale or distribution of natural gas and electricity. The following table presents the excise taxes recorded on a gross basis in “Operating Revenues – Electric,” “Operating Revenues – Natural gas” and “Operating Expenses – Taxes other than income taxes” on the statements of income for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months			Three Months						Six Months
			2023			2022			2023		2022		2023		2022
Ameren Missouri	Ameren Missouri		$	34		$	34	Ameren Missouri	$	39	$	39	$	73	$	73
Ameren Illinois	Ameren Illinois		37			45		Ameren Illinois	26		28		63		73
Ameren	Ameren		$	71		$	79	Ameren	$	65	$	67	$	136	$	146

3537

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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 six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months		Three Months				Six Months
			2023		2022		2023	2022	2023	2022

Weighted-average Common Shares Outstanding – Basic	Weighted-average Common Shares Outstanding – Basic		262.2		257.9	Weighted-average Common Shares Outstanding – Basic	262.6	258.2	262.4	258.0
Assumed settlement of performance share units and restricted stock units	Assumed settlement of performance share units and restricted stock units		0.9		1.1	Assumed settlement of performance share units and restricted stock units	0.6	1.0	0.8	1.1

Dilutive effect of forward sale agreements						Dilutive effect of forward sale agreements	—	0.2	—	0.1
Weighted-average Common Shares Outstanding – Diluted(a)	Weighted-average Common Shares Outstanding – Diluted(a)		263.1		259.0	Weighted-average Common Shares Outstanding – Diluted(a)	263.2	259.4	263.2	259.2

(a)There was an immaterial number of anti-dilutive performance share units excluded from the earnings per diluted share calculations for the three and six months ended ~~March 31,~~June 30, 2023 and 2022. The outstanding forward sale agreements as of ~~March 31,~~June 30, 2023, were anti-dilutive for the three and six months ended June 30, 2023, and excluded from the earnings per diluted share calculation as calculated using the treasury stock method.

NOTE 14 – SEGMENT INFORMATION

The following tables present revenues, net income attributable to common shareholders, and capital expenditures by segment at Ameren and Ameren Illinois for the three and six months ended ~~March 31,~~June 30, 2023 and 2022. Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount. For additional information about our segments, see Note 16 – Segment Information under Part II, Item 8, of the Form 10-K.

Ameren


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

																		Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission			Other		Intersegment Eliminations		Ameren
Three Months 2023:	Three Months 2023:																Three Months 2023:
External revenues	External revenues	$	913	$	624	$	391	$	134		$	—	$	—	$	2,062	External revenues	$	933	$	540	$	152	$	135		$	—	$	—	$	1,760
Intersegment revenues	Intersegment revenues	10		—		—		29			—		(39)		—		Intersegment revenues	8		—		—		26			—		(34)		—
Net income attributable to Ameren common shareholders		28		61		87		71		(a)	17		—		264
Net income (loss) attributable to Ameren common shareholders																	Net income (loss) attributable to Ameren common shareholders	102		66		11		72		(a)	(14)		—		237
Capital expenditures	Capital expenditures	481		170		51		213			3		13		931		Capital expenditures	433		180		90		197			2		(11)		891
Three Months 2022:	Three Months 2022:																Three Months 2022:
External revenues	External revenues	$	808	$	464	$	481	$	126		$	—	$	—	$	1,879	External revenues	$	912	$	504	$	184	$	126		$	—	$	—	$	1,726
Intersegment revenues	Intersegment revenues	10		1		—		20			—		(31)		—		Intersegment revenues	7		—		—		24			—		(31)		—
Net income (loss) attributable to Ameren common shareholders																	Net income (loss) attributable to Ameren common shareholders	100		51		6		63		(a)	(13)		—		207
Capital expenditures																	Capital expenditures	392		143		69		160			1		(1)		764
Six Months 2023:																	Six Months 2023:
External revenues																	External revenues	$	1,846	$	1,164	$	543	$	269		$	—	$	—	$	3,822
Intersegment revenues																	Intersegment revenues	18		—		—		55			—		(73)		—
Net income attributable to Ameren common shareholders	Net income attributable to Ameren common shareholders	50		49		80		58		(a)	15		—		252		Net income attributable to Ameren common shareholders	130		127		98		143		(a)	3		—		501
Capital expenditures	Capital expenditures	414		138		49		172			2		(1)		774		Capital expenditures	914		350		141		410			5		2		1,822
Six Months 2022:																	Six Months 2022:
External revenues																	External revenues	$	1,720	$	968	$	665	$	252		$	—	$	—	$	3,605
Intersegment revenues																	Intersegment revenues	17		1		—		44			—		(62)		—
Net income attributable to Ameren common shareholders																	Net income attributable to Ameren common shareholders	150		100		86		121		(a)	2		—		459
Capital expenditures																	Capital expenditures	806		281		118		332			3		(2)		1,538

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

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Ameren Illinois


		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Intersegment Eliminations		Ameren Illinois

													Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Intersegment Eliminations		Ameren Illinois
Three Months 2023:	Three Months 2023:											Three Months 2023:
External revenues	External revenues	$	624	$	391	$	86	$	—	$	1,101	External revenues	$	540	$	152	$	87	$	—	$	779
Intersegment revenues	Intersegment revenues	—		—		28		(28)		—		Intersegment revenues	—		—		26		(26)		—
Net income available to common shareholder	Net income available to common shareholder	61		87		50		—		198		Net income available to common shareholder	66		11		52		—		129
Capital expenditures	Capital expenditures	170		51		186		—		407		Capital expenditures	180		90		167		—		437
Three Months 2022:	Three Months 2022:											Three Months 2022:
External revenues	External revenues	$	465	$	481	$	78	$	—	$	1,024	External revenues	$	504	$	184	$	81	$	—	$	769
Intersegment revenues	Intersegment revenues	—		—		20		(20)		—		Intersegment revenues	—		—		24		(24)		—
Net income available to common shareholder	Net income available to common shareholder	49		80		40		—		169		Net income available to common shareholder	51		6		46		—		103
Capital expenditures	Capital expenditures	138		49		155		—		342		Capital expenditures	143		69		145		—		357
Six Months 2023:												Six Months 2023:
External revenues												External revenues	$	1,164	$	543	$	173	$	—	$	1,880
Intersegment revenues												Intersegment revenues	—		—		54		(54)		—
Net income available to common shareholder												Net income available to common shareholder	127		98		102		—		327
Capital expenditures												Capital expenditures	350		141		353		—		844
Six Months 2022:												Six Months 2022:
External revenues												External revenues	$	969	$	665	$	159	$	—	$	1,793
Intersegment revenues												Intersegment revenues	—		—		44		(44)		—
Net income available to common shareholder												Net income available to common shareholder	100		86		86		—		272
Capital expenditures												Capital expenditures	281		118		300		—		699

The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and six months ended ~~March 31,~~June 30, 2023 and 2022. 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 2023:
Residential	$	360	$	337		$	—	$	—	$	—	$	697
Commercial	311		193			—		—		—		504
Industrial	75		48			—		—		—		123
Other	172		(38)		(a)	—		161		(34)		261
Total electric revenues	$	918	$	540		$	—	$	161	$	(34)	$	1,585
Residential	$	13	$	—		$	98	$	—	$	—	$	111
Commercial	6		—			25		—		—		31
Industrial	1		—			2		—		—		3
Other	3		—			27		—		—		30
Total natural gas revenues	$	23	$	—		$	152	$	—	$	—	$	175
Total revenues(b)	$	941	$	540		$	152	$	161	$	(34)	$	1,760

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~~Ameren~~


	Ameren Missouri		Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas		Ameren Transmission		Intersegment Eliminations		Ameren
Three Months 2022:
Residential	$	371	$	284		$	—	$	—	$	—	$	655
Commercial	298		180			—		—		—		478
Industrial	73		53			—		—		—		126
Other	148		(13)		(a)	—		150		(31)		254
Total electric revenues	$	890	$	504		$	—	$	150	$	(31)	$	1,513
Residential	$	16	$	—		$	117	$	—	$	—	$	133
Commercial	8		—			30		—		—		38
Industrial	1		—			11		—		—		12
Other	4		—			26		—		—		30
Total natural gas revenues	$	29	$	—		$	184	$	—	$	—	$	213
Total revenues(b)	$	919	$	504		$	184	$	150	$	(31)	$	1,726
Six Months 2023:
Residential	$	684	$	719		$	—	$	—	$	—	$	1,403
Commercial	558		393			—		—		—		951
Industrial	136		96			—		—		—		232
Other	381		(44)		(a)	—		324		(72)		589
Total electric revenues	$	1,759	$	1,164		$	—	$	324	$	(72)	$	3,175
Residential	$	65	$	—		$	394	$	—	$	—	$	459
Commercial	29		—			102		—		—		131
Industrial	3		—			9		—		—		12
Other	8		—			38		—		(1)		45
Total natural gas revenues	$	105	$	—		$	543	$	—	$	(1)	$	647
Total revenues(b)	$	1,864	$	1,164		$	543	$	324	$	(73)	$	3,822
Six Months 2022:
Residential	$	703	$	547		$	—	$	—	$	—	$	1,250
Commercial	538		338			—		—		—		876
Industrial	130		98			—		—		—		228
Other	257		(14)		(a)	—		296		(62)		477
Total electric revenues	$	1,628	$	969		$	—	$	296	$	(62)	$	2,831
Residential	$	67	$	—		$	486	$	—	$	—	$	553
Commercial	30		—			127		—		—		157
Industrial	3		—			28		—		—		31
Other	9		—			24		—		—		33
Total natural gas revenues	$	109	$	—		$	665	$	—	$	—	$	774
Total revenues(b)	$	1,737	$	969		$	665	$	296	$	(62)	$	3,605

Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren
Three Months 2023:
Residential $ 324 $ 382 $ — $ — $ — $ 706
Commercial 247 200 — — — 447
Industrial 61 48 — — — 109
Other 209 (6) — 163 (38) 328
Total electric revenues $ 841 $ 624 $ — $ 163 $ (38) $ 1,590
Residential $ 52 $ — $ 296 $ — $ — $ 348
Commercial 23 — 77 — — 100
Industrial 2 — 7 — — 9
Other 5 — 11 — (1) 15
Total natural gas revenues $ 82 $ — $ 391 $ — $ (1) $ 472
Total revenues(a)
$ 923 $ 624 $ 391 $ 163 $ (39) $ 2,062
Three Months 2022:
Residential $ 332 $ 263 $ — $ — $ — $ 595
Commercial 240 158 — — — 398
Industrial 57 45 — — — 102
Other 109 (1) — 146 (31) 223
Total electric revenues $ 738 $ 465 $ — $ 146 $ (31) $ 1,318
Residential $ 51 $ — $ 369 $ — $ — $ 420
Commercial 22 — 97 — — 119
Industrial 2 — 17 — — 19
Other 5 — (2) — — 3
Total natural gas revenues $ 80 $ — $ 481 $ — $ — $ 561
Total revenues(a)
$ 818 $ 465 $ 481 $ 146 $ (31) $ 1,879

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(a)Includes over-recoveries of various riders.

(b)The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Ameren Missouri			Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission		Ameren

															Ameren Missouri			Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission		Ameren
Three Months 2023:	Three Months 2023:													Three Months 2023:
Revenues from alternative revenue programs	Revenues from alternative revenue programs	$	(2)		$	64	$	28	$	8	$	98		Revenues from alternative revenue programs	$	—		$	60	$	9	$	5	$	74
Other revenues not from contracts with customers	Other revenues not from contracts with customers	(6)		(a)	2		1		—		(3)		(a)	Other revenues not from contracts with customers	(2)		(a)	2		1		—		1		(a)
Three Months 2022:	Three Months 2022:													Three Months 2022:
Revenues from alternative revenue programs	Revenues from alternative revenue programs	$	(6)		$	55	$	(5)	$	1	$	45		Revenues from alternative revenue programs	$	—		$	41	$	3	$	(4)	$	40
Other revenues not from contracts with customers	Other revenues not from contracts with customers	—		(a)	2		1		—		3		(a)	Other revenues not from contracts with customers	(36)		(a)	1		1		—		(34)		(a)
Six Months 2023:														Six Months 2023:
Revenues from alternative revenue programs														Revenues from alternative revenue programs	$	(2)		$	124	$	37	$	13	$	172
Other revenues not from contracts with customers														Other revenues not from contracts with customers	(8)		(a)	4		2		—		(2)		(a)
Six Months 2022:														Six Months 2022:
Revenues from alternative revenue programs														Revenues from alternative revenue programs	$	(6)		$	96	$	(2)	$	(3)	$	85
Other revenues not from contracts with customers														Other revenues not from contracts with customers	(36)		(a)	3		2		—		(31)		(a)

(a)Includes net realized losses on derivative power contracts.

Ameren Illinois


	Ameren Illinois Electric Distribution			Ameren Illinois Natural Gas		Ameren Illinois Transmission		Intersegment Eliminations		Ameren Illinois
Three Months 2023:
Residential	$	337		$	98	$	—	$	—	$	435
Commercial	193			25		—		—		218
Industrial	48			2		—		—		50
Other	(38)		(a)	27		113		(26)		76
Total revenues(b)	$	540		$	152	$	113	$	(26)	$	779
Three Months 2022:
Residential	$	284		$	117	$	—	$	—	$	401
Commercial	180			30		—		—		210
Industrial	53			11		—		—		64
Other	(13)		(a)	26		105		(24)		94
Total revenues(b)	$	504		$	184	$	105	$	(24)	$	769
Six Months 2023:
Residential	$	719		$	394	$	—	$	—	$	1,113
Commercial	393			102		—		—		495
Industrial	96			9		—		—		105
Other	(44)		(a)	38		227		(54)		167
Total revenues(b)	$	1,164		$	543	$	227	$	(54)	$	1,880
Six Months 2022:
Residential	$	547		$	486	$	—	$	—	$	1,033
Commercial	338			127		—		—		465
Industrial	98			28		—		—		126
Other	(14)		(a)	24		203		(44)		169
Total revenues(b)	$	969		$	665	$	203	$	(44)	$	1,793

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~~Ameren Illinois~~

Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois
Three Months 2023:
Residential $ 382 $ 296 $ — $ — $ 678
Commercial 200 77 — — 277
Industrial 48 7 — — 55
Other (6) 11 114 (28) 91
Total revenues(a)
$ 624 $ 391 $ 114 $ (28) $ 1,101
Three Months 2022:
Residential $ 263 $ 369 $ — $ — $ 632
Commercial 158 97 — — 255
Industrial 45 17 — — 62
Other (1) (2) 98 (20) 75
Total revenues(a)
$ 465 $ 481 $ 98 $ (20) $ 1,024
(a)Includes over-recoveries of various riders.

~~(a)~~(b)The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Ameren Illinois

											Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Ameren Illinois
Three Months 2023:	Three Months 2023:									Three Months 2023:
Revenues from alternative revenue programs	Revenues from alternative revenue programs	$	64	$	28	$	7	$	99	Revenues from alternative revenue programs	$	60	$	9	$	3	$	72
Other revenues not from contracts with customers	Other revenues not from contracts with customers	2		1		—		3		Other revenues not from contracts with customers	2		1		—		3

Three Months 2022:	Three Months 2022:									Three Months 2022:
Revenues from alternative revenue programs	Revenues from alternative revenue programs	$	55	$	(5)	$	1	$	51	Revenues from alternative revenue programs	$	41	$	3	$	(3)	$	41
Other revenues not from contracts with customers	Other revenues not from contracts with customers	2		1		—		3		Other revenues not from contracts with customers	1		1		—		2

Six Months 2023:										Six Months 2023:
Revenues from alternative revenue programs										Revenues from alternative revenue programs	$	124	$	37	$	10	$	171
Other revenues not from contracts with customers										Other revenues not from contracts with customers	4		2		—		6

Six Months 2022:										Six Months 2022:
Revenues from alternative revenue programs										Revenues from alternative revenue programs	$	96	$	(2)	$	(2)	$	92
Other revenues not from contracts with customers										Other revenues not from contracts with customers	3		2		—		5

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 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.

In addition to presenting results of operations and earnings amounts in total, we present certain information in cents per share. These amounts reflect factors that directly affect Ameren’s earnings. We believe this per share information helps readers to understand the impact of these factors on Ameren’s earnings per share.

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OVERVIEW

Net income attributable to Ameren common shareholders in the three months ended ~~March 31,~~June 30, 2023, was ~~$264~~$237 million, or ~~$1.00~~$0.90 per diluted share, compared with ~~$252~~$207 million, or ~~$0.97~~$0.80 per diluted share, in the year-ago period. Net income attributable to Ameren common shareholders in the six months ended June 30, 2023, was $501 million, or $1.90 per diluted share, compared with $459 million, or $1.77 per diluted share, in the year-ago period. Net income for the three and six months ended ~~March 31,~~June 30, 2023, was favorably affected by increased rate base investments across all segments, a higher recognized ROE at Ameren Illinois Electric Distribution due to a higher estimated annual average of the monthly yields of the 30-year United States Treasury bonds, and decreased other operations and maintenance expenses not subject to formula rates, riders, or trackers, including an increase in the cash surrender value of COLI. Net income for the three and six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period,~~periods, was unfavorably affected by decreased electric retail sales at Ameren Missouri, primarily resulting from milder spring and early summer temperatures in the three month period ended June 30, 2023, as well as

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warmer winter temperatures ~~experienced~~ in the six month period ended June 30, 2023, compared with the same periods in 2022; and increased financing costs from the issuance of long-term debt at Ameren Missouri and higher interest rates on increased levels of short-term borrowings.

Ameren’s strategic plan includes investing in rate-regulated energy infrastructure, enhancing regulatory frameworks and advocating for responsible policies, and optimizing operating performance to capitalize on opportunities to benefit our customers, our shareholders, and the environment. Ameren remains focused on disciplined cost management and strategic capital allocation. Ameren invested ~~$0.9~~$1.8 billion in its rate-regulated businesses in the ~~three~~six months ended ~~March 31,~~June 30, 2023.

In ~~April~~June 2023, ~~Ameren Missouri,~~ the MoPSC ~~staff, the MoOPC, and certain intervenors filed a nonunanimous stipulation and agreement with the MoPSC~~issued an order that resulted in an increase of $140 million to ~~increase~~ Ameren Missouri’s annual ~~revenues~~revenue requirement for electric ~~service by $140 million.~~retail service. The ~~remaining intervenors~~approved revenue requirement is based on infrastructure investments as of December 31, 2022, and included an extension of the depreciable lives of the Sioux Energy Center’s assets from 2028 to 2030. The order did not ~~object to the agreement. The stipulation and agreement, which is subject to MoPSC approval, did not~~explicitly specify an ~~allowed~~ ROE, capital structure, or rate ~~base, or any rate base disallowances.~~base. The ~~stipulation and agreement includes~~order provides for the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable energy standard costs that the MoPSC previously authorized in earlier electric rate orders, as well as the use of an electric property tax tracker. It also includes a tracker for ~~future~~the utilization of production and investment tax credits ~~and~~or proceeds from the sale of tax credits allowed under the IRA. ~~A decision~~The order increased the annualized base level of net energy costs pursuant to the FAC by approximately $40 million from the base level established in the MoPSC’s December 2021 electric rate order. The order also changed annualized depreciation, regulatory asset and liability amortization amounts, and the base level of expenses for trackers. On an annualized basis, these changes reflect approximate increases in “Depreciation and amortization” of $90 million and “Other income, net”, of $100 million, related to non-service pension and postretirement benefit income, on Ameren’s and Ameren Missouri’s consolidated statements of income. The new rates became effective on July 9, 2023.

In June 2023, Ameren Missouri filed for CCNs with the MoPSC onfor four solar generation facilities and expects decisions in the ~~nonunanimous stipulation and agreement is expected by June 2023, with new rates expected to take effect on July 1, 2023.~~

~~In April 2023,~~first quarter of 2024. These facilities include the ~~MoPSC issued an order approving a requested CCN for~~Split Rail Solar Project (300-MW facility, build-transfer agreement), the ~~Boomtown~~Cass County Solar ~~Project.~~ In February 2023, the MoPSC issued an order approving a nonunanimous stipulation and agreement regarding a requested CCN for the Huck Finn Solar Project. In 2022, Ameren Missouri entered into an engineering, supply, and construction agreement to constructProject (150-MW facility, development-transfer agreement), the Vandalia Solar Project ~~a 50-MW solar generation~~(50-MW facility, self-build), and the Bowling Green Solar Project (50-MW facility, self-build). The Cass County Solar Project is expected to be located in central ~~Missouri~~Illinois and the other three projects are expected to be located in central Missouri. Each project is expected to support Ameren Missouri’s transition to renewable generation. ~~Ameren Missouri expects to construct the Vandalia Solar Project after obtaining a CCN from~~In February and April 2023, the MoPSC ~~which it expects to file by mid-2023.~~issued orders approving requested CCNs for the Huck Finn and Boomtown solar projects, respectively.

In February 2023, Ameren Missouri filed an update to its Smart Energy Plan with the MoPSC, which includes a five-year capital investment overview with a detailed one-year plan for 2023. The plan is designed to upgrade Ameren Missouri’s electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $9.9 billion over the five-year period from 2023 through 2027, with expenditures largely recoverable under the PISA and the RESRAM. Ameren Missouri’s Smart Energy Plan excludes investments in its natural gas distribution business, as well as removal costs, net of salvage.

In ~~April~~July 2023, Ameren Illinois filed ~~for~~ a reconciliation adjustment to its 2022 electric distribution service revenue requirement with the ICC, requesting recovery of $127 million. The reconciliation adjustment reflects Ameren Illinois’ actual 2022 recoverable costs, year-end rate base, and capital structure, which was composed of 54% common equity. An ICC decision in this proceeding is required by December 2023, and any approved adjustment would be collected from customers in 2024.

~~In January 2023, Ameren Illinois filed an~~revised MYRP with the ICC to be used in setting electric distribution service rates for 2024 through 2027. Under the MYRP, the ICC would approve base rates for electric distribution service to be charged to customers for each calendar year

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of the four-year period. The following table includes the forecasted revenue requirement, the requested ROE, the requested capital structure common equity percentage, and the forecasted average annual rate base for 2024 through 2027, as reflected in Ameren Illinois’ ~~MYRP:~~revised MYRP filing:


Year	Year	Forecasted Revenue Requirement (in millions)	Requested ROE	Requested Capital Structure Common Equity Percentage(a)	Forecasted Average Annual Rate Base (in billions)	Year	Forecasted Revenue Requirement (in millions)(a)	Requested ROE	Requested Capital Structure Common Equity Percentage(b)	Forecasted Average Annual Rate Base (in billions)
2024	2024	$1,282	10.5%	53.99%	$4.3	2024	$1,291	10.5%	53.99%	$4.3
2025	2025	$1,373	10.5%	53.97%	$4.6	2025	$1,387	10.5%	53.97%	$4.6
2026	2026	$1,477	10.5%	54.02%	$5.0	2026	$1,484	10.5%	54.02%	$4.9
2027	2027	$1,556	10.5%	54.03%	$5.3	2027	$1,560	10.5%	54.03%	$5.2

(b)A capital structure of up to and including 50% common equity is deemed prudent and reasonable by law. A higher equity ratio requires specific ICC approval.

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In ~~January~~July 2023, Ameren Illinois filed a revised reconciliation adjustment to its 2022 electric distribution service revenue requirement with the ICC, requesting recovery of $125 million. The reconciliation adjustment reflects Ameren Illinois’ actual 2022 recoverable costs, year-end rate base, and capital structure, which was composed of 54% common equity. An ICC decision in this proceeding is required by December 2023, and any approved adjustment would be collected from customers in 2024.

In July 2023, Ameren Illinois filed a revised request with the ICC seeking approval to increase its annual revenues for natural gas delivery service by ~~$160~~$148 million, which ~~included~~includes an estimated $77 million of annual revenues that would otherwise be recovered under the QIP and other riders. The request is based on a ~~10.7%~~10.3% allowed ROE, a capital structure composed of 53.99% common equity, and a rate base of $2.9 billion. In an attempt to reduce regulatory lag, Ameren Illinois used a 2024 future test year in this proceeding. A decision by the ICC in this proceeding is required by late November 2023, with new rates expected to be effective in early December 2023.

For further information on the matters discussed above, see Note 2 – Rate and Regulatory Matters under Part I, Item I, of this report, and the Outlook section below.

RESULTS OF OPERATIONS

Our results of operations and financial position are affected by many factors. Economic conditions, energy-efficiency investments by our customers and by us, technological advances, distributed generation, and the actions of key customers can significantly affect the demand for our services. Ameren and Ameren Missouri results are also affected by seasonal fluctuations in winter heating and summer cooling demands and by weather conditions, such as storms, as well as by energy center maintenance outages. Additionally, fluctuations in interest rates and conditions in the capital and credit markets affect our cost of borrowing, our pension and postretirement benefits costs, the cash surrender value of COLI, and the asset value of Ameren Missouri’s nuclear decommissioning trust fund. Almost all of Ameren’s revenues are subject to state or federal regulation. This regulation has a material impact on the rates we charge customers for our services. Our results of operations, financial position, and liquidity are affected by our ability to align our overall spending, both operating and capital, with the frameworks established by our regulators. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of the Form 10-K for additional information regarding Ameren Missouri’s, Ameren Illinois’, and ATXI’s regulatory mechanisms.

We are observing inflationary pressures on the prices of certain commodities, labor, services, materials, and supplies, as well as increasing interest rates. Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel, purchased power, and natural gas supply. Additionally, for certain non-commodity cost changes, the use of trackers, riders, ~~and~~ formula ratemaking, and future test years, as applicable, mitigates our exposure.

Ameren Missouri principally uses coal and enriched uranium for fuel in its electric operations and purchases natural gas for its customers. Ameren Illinois purchases power and natural gas for its customers. The prices for these commodities can fluctuate significantly because of the global economic and political environment, weather, supply, demand, and many other factors. We have natural gas cost recovery mechanisms for our Illinois and Missouri natural gas distribution businesses, a purchased power cost recovery mechanism for Ameren Illinois’ electric distribution business, and a FAC for Ameren Missouri’s electric business.

We employ various risk management strategies to reduce our exposure to commodity risk and other risks inherent in our business. The reliability of Ameren Missouri’s energy centers and our transmission and distribution systems, and the level and timing of operations and maintenance costs and capital investment, are key factors that we seek to manage in order to optimize our results of operations, financial position, and liquidity.

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Earnings Summary

The following table presents a summary of Ameren’s earnings for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months			Three Months						Six Months
			2023			2022			2023		2022		2023		2022
Net income attributable to Ameren common shareholders	Net income attributable to Ameren common shareholders		$	264		$	252	Net income attributable to Ameren common shareholders	$	237	$	207	$	501	$	459
Earnings per common share – diluted	Earnings per common share – diluted		1.00			0.97		Earnings per common share – diluted	0.90		0.80		1.90		1.77

Net income attributable to Ameren common shareholders increased ~~$12~~$30 million, or 310 cents per diluted share, in the three months ended ~~March 31,~~June 30, 2023, compared with the year-ago period, primarily due to net income increases of $15 million, $9 million, $5 million, and $2 million at Ameren Illinois Electric Distribution, Ameren Transmission, Ameren Illinois Natural Gas and Ameren Missouri, respectively.

Net income attributable to Ameren common shareholders increased $42 million, or 13 cents per diluted share, in the six months ended June 30, 2023, compared with the year-ago period. The increase was due to net income increases of ~~$13~~$27 million, $22 million, and $12 million ~~$7 million, and $2 million~~ at ~~Ameren Transmission,~~ Ameren Illinois Electric Distribution, Ameren Transmission, and Ameren Illinois Natural Gas, ~~and activity not reported as part of a segment, primarily at Ameren (parent), respectively. These earnings increases were~~respectively, partially offset by a ~~$22~~$20 million net income decrease at Ameren Missouri.

Earnings per diluted share were favorably affected in the three and six months ended ~~March 31,~~June 30, 2023, compared to the year-ago periods (except where a specific period is referenced), by:

•decreased other operations and maintenance expenses not subject to formula rates, riders, or trackers, including an increase in the cash surrender value of COLI, primarily at Ameren Missouri and Ameren Illinois Natural Gas (9 cents and 12 cents per share, respectively);

•increased rate base investments at Ameren Transmission and Ameren Illinois Electric Distribution and a higher recognized ROE due to a higher estimated annual average of the monthly yields of the 30-year United States Treasury bonds at Ameren Illinois Electric Distribution, which increased revenues at these segments (7(5 cents and 12 cents per ~~share);~~

•~~decreased other operations and maintenance expenses not subject to formula rates, riders, or trackers, including an increase in the cash surrender value of COLI (3 cents per share);~~

•decreased taxes other than income taxes, primarily at Ameren Missouri, largely resulting from employee retention tax credits received under the Coronavirus Aid, Relief, and Economic Security Act (2 cents per share)share, respectively);

•increased base rate revenues at Ameren Missouri for the inclusion of previously deferred interest charges pursuant to the December 2021 MoPSC electric rate order effective February 28, 2022, partially offset in the six months ended June 30, 2023, by increased interest charges resulting from lower deferrals related to infrastructure investments associated with the PISA and RESRAM (2 cents and 4 cents per ~~share)~~share, respectively);

•increased other income, net, largely due to increased non-service cost components of net periodic benefit income not subject to formula rates or trackers (2 cents per ~~share)~~share for the six months ended June 30, 2023);

•decreased income tax expense not subject to formula rates or riders, resulting, in part, from the effect of favorable market returns on COLI, compared with unfavorable returns in the year-ago periods (2 cents per share for both periods);

•recovery of previously incurred expenses at Ameren Illinois Electric Distribution (2 cents per share for both periods);

•increased base rate revenues at Ameren Missouri effective February 28, 2022, pursuant to the December 2021 MoPSC electric rate order, partially offset by the amortization of previously deferred depreciation expense under the PISA and RESRAM, financing costs otherwise recoverable under the PISA and RESRAM, a higher base level of expenses, and the net recovery for amounts associated with the reduction in sales volumes resulting from MEEIA programs (1 cent per ~~share)~~share for the six months ended June 30, 2023); and

•increased Ameren Illinois Natural Gas earnings from investments in qualifying infrastructure recovered under the QIP (1 cent per ~~share)~~share for the six months ended June 30, 2023).

Earnings per diluted share were unfavorably affected in the three and six months ended ~~March 31,~~June 30, 2023, compared to the year-ago ~~period,~~periods, by:

•decreased electric retail sales at Ameren Missouri, primarily resulting from milder spring and early summer temperatures in the three months ended June 30, 2023, as well as warmer winter temperatures ~~experienced~~ in the six months ended June 30, 2023, compared with the same periods in 2022 (estimated at 106 cents and 16 cents per ~~share)~~share, respectively);

•increased financing costs, primarily at Ameren ~~Missouri~~(parent) and Ameren ~~(parent),~~Missouri, due to higher interest rates on increased levels of short-term borrowings and higher long-term debt balances at Ameren Missouri (3 cents and ~~higher interest rates on short-term borrowings (4~~7 cents per ~~share)~~share, respectively); and

•increased weighted-average basic common shares outstanding resulting from issuances of common shares as detailed in Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report, and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K (2(1 cent and 3 cents per ~~share)~~share, respectively).

Table of Contents

The cents per share variances above are presented based on the weighted-average basic common shares outstanding in the three and six months ended ~~March 31,~~June 30, 2022, 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 2023 blended federal and state statutory tax rate of 26%. For additional details regarding the Ameren Companies’ results of operations, including explanations of Electric and Natural Gas Margins; 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.

Table of Contents

Below is Ameren’s table of income statement components by segment for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


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

															Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission		Other / Intersegment Eliminations		Ameren
Three Months 2023:	Three Months 2023:													Three Months 2023:
Electric revenues	Electric revenues	$	841	$	624	$	—	$	163	$	(38)	$	1,590	Electric revenues	$	918	$	540	$	—	$	161	$	(34)	$	1,585
Fuel	Fuel	(113)		—		—		—		—		(113)		Fuel	(152)		—		—		—		—		(152)
Purchased power	Purchased power	(208)		(315)		—		—		28		(495)		Purchased power	(137)		(218)		—		—		27		(328)
Electric margins	Electric margins	520		309		—		163		(10)		982		Electric margins	629		322		—		161		(7)		1,105
Natural gas revenues	Natural gas revenues	82		—		391		—		(1)		472		Natural gas revenues	23		—		152		—		—		175
Natural gas purchased for resale	Natural gas purchased for resale	(47)		—		(161)		—		—		(208)		Natural gas purchased for resale	(9)		—		(33)		—		—		(42)
Natural gas margins	Natural gas margins	35		—		230		—		(1)		264		Natural gas margins	14		—		119		—		—		133
Other operations and maintenance expenses	Other operations and maintenance expenses	(239)		(129)		(59)		(16)		(5)		(448)		Other operations and maintenance expenses	(237)		(133)		(58)		(13)		(9)		(450)
Depreciation and amortization expenses	Depreciation and amortization expenses	(176)		(84)		(26)		(33)		(1)		(320)		Depreciation and amortization expenses	(186)		(87)		(27)		(34)		(1)		(335)
Taxes other than income taxes	Taxes other than income taxes	(80)		(18)		(23)		(2)		(4)		(127)		Taxes other than income taxes	(88)		(18)		(13)		(2)		(3)		(124)
Operating income (loss)	Operating income (loss)	60		78		122		112		(21)		351		Operating income (loss)	132		84		21		112		(20)		329
Other income, net	Other income, net	19		24		8		6		21		78		Other income, net	22		26		8		8		18		82
Interest charges	Interest charges	(51)		(21)		(13)		(22)		(20)		(127)		Interest charges	(52)		(22)		(13)		(23)		(24)		(134)
Income (taxes) benefit	Income (taxes) benefit	1		(20)		(30)		(25)		37		(37)		Income (taxes) benefit	1		(21)		(5)		(25)		12		(38)
Net income		29		61		87		71		17		265
Net income (loss)														Net income (loss)	103		67		11		72		(14)		239
Noncontrolling interests – preferred stock dividends	Noncontrolling interests – preferred stock dividends	(1)		—		—		—		—		(1)		Noncontrolling interests – preferred stock dividends	(1)		(1)		—		—		—		(2)
Net income attributable to Ameren common shareholders		$	28	$	61	$	87	$	71	$	17	$	264
Net income (loss) attributable to Ameren common shareholders														Net income (loss) attributable to Ameren common shareholders	$	102	$	66	$	11	$	72	$	(14)	$	237
Three Months 2022:	Three Months 2022:													Three Months 2022:
Electric revenues	Electric revenues	$	738	$	465	$	—	$	146	$	(31)	$	1,318	Electric revenues	$	890	$	504	$	—	$	150	$	(31)	$	1,513
Fuel	Fuel	(176)		—		—		—		—		(176)		Fuel	(83)		—		—		—		—		(83)
Purchased power	Purchased power	(50)		(151)		—		—		24		(177)		Purchased power	(161)		(182)		—		—		25		(318)
Electric margins	Electric margins	512		314		—		146		(7)		965		Electric margins	646		322		—		150		(6)		1,112
Natural gas revenues	Natural gas revenues	80		—		481		—		—		561		Natural gas revenues	29		—		184		—		—		213
Natural gas purchased for resale	Natural gas purchased for resale	(46)		—		(247)		—		—		(293)		Natural gas purchased for resale	(12)		—		(68)		—		—		(80)
Natural gas margins	Natural gas margins	34		—		234		—		—		268		Natural gas margins	17		—		116		—		—		133
Other operations and maintenance expenses	Other operations and maintenance expenses	(232)		(147)		(63)		(16)		(3)		(461)		Other operations and maintenance expenses	(260)		(148)		(63)		(16)		(4)		(491)
Depreciation and amortization expenses	Depreciation and amortization expenses	(164)		(81)		(23)		(30)		(1)		(299)		Depreciation and amortization expenses	(178)		(82)		(25)		(30)		(1)		(316)
Taxes other than income taxes	Taxes other than income taxes	(85)		(20)		(31)		(2)		(4)		(142)		Taxes other than income taxes	(90)		(19)		(16)		(2)		(2)		(129)
Operating income (loss)	Operating income (loss)	65		66		117		98		(15)		331		Operating income (loss)	135		73		12		102		(13)		309
Other income, net	Other income, net	23		16		4		3		14		60		Other income, net	24		15		6		4		13		62
Interest charges	Interest charges	(39)		(18)		(11)		(22)		(14)		(104)		Interest charges	(60)		(18)		(11)		(20)		(17)		(126)
Income (taxes) benefit	Income (taxes) benefit	2		(15)		(30)		(21)		30		(34)		Income (taxes) benefit	2		(18)		(1)		(23)		4		(36)
Net income		51		49		80		58		15		253
Net income (loss)														Net income (loss)	101		52		6		63		(13)		209
Noncontrolling interests – preferred stock dividends	Noncontrolling interests – preferred stock dividends	(1)		—		—		—		—		(1)		Noncontrolling interests – preferred stock dividends	(1)		(1)		—		—		—		(2)
Net income attributable to Ameren common shareholders		$	50	$	49	$	80	$	58	$	15	$	252
Net income (loss) attributable to Ameren common shareholders														Net income (loss) attributable to Ameren common shareholders	$	100	$	51	$	6	$	63	$	(13)	$	207

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	Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission		Other / Intersegment Eliminations		Ameren
Six Months 2023:
Electric revenues	$	1,759	$	1,164	$	—	$	324	$	(72)	$	3,175
Fuel	(265)		—		—		—		—		(265)
Purchased power	(345)		(533)		—		—		55		(823)
Electric margins	1,149		631		—		324		(17)		2,087
Natural gas revenues	105		—		543		—		(1)		647
Natural gas purchased for resale	(56)		—		(194)		—		—		(250)
Natural gas margins	49		—		349		—		(1)		397
Other operations and maintenance expenses	(476)		(262)		(117)		(29)		(14)		(898)
Depreciation and amortization expenses	(362)		(171)		(53)		(67)		(2)		(655)
Taxes other than income taxes	(168)		(36)		(36)		(4)		(7)		(251)
Operating income (loss)	192		162		143		224		(41)		680
Other income, net	41		50		16		14		39		160
Interest charges	(103)		(43)		(26)		(45)		(44)		(261)
Income (taxes) benefit	2		(41)		(35)		(50)		49		(75)
Net income	132		128		98		143		3		504
Noncontrolling interests – preferred stock dividends	(2)		(1)		—		—		—		(3)
Net income attributable to Ameren common shareholders	$	130	$	127	$	98	$	143	$	3	$	501
Six Months 2022:
Electric revenues	$	1,628	$	969	$	—	$	296	$	(62)	$	2,831
Fuel	(259)		—		—		—		—		(259)
Purchased power	(211)		(333)		—		—		49		(495)
Electric margins	1,158		636		—		296		(13)		2,077
Natural gas revenues	109		—		665		—		—		774
Natural gas purchased for resale	(58)		—		(315)		—		—		(373)
Natural gas margins	51		—		350		—		—		401
Other operations and maintenance expenses	(492)		(295)		(126)		(32)		(7)		(952)
Depreciation and amortization expenses	(342)		(163)		(48)		(60)		(2)		(615)
Taxes other than income taxes	(175)		(39)		(47)		(4)		(6)		(271)
Operating income (loss)	200		139		129		200		(28)		640
Other income, net	47		31		10		7		27		122
Interest charges	(99)		(36)		(22)		(42)		(31)		(230)
Income (taxes) benefit	4		(33)		(31)		(44)		34		(70)
Net income	152		101		86		121		2		462
Noncontrolling interests – preferred stock dividends	(2)		(1)		—		—		—		(3)
Net income attributable to Ameren common shareholders	$	150	$	100	$	86	$	121	$	2	$	459

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Below is Ameren Illinois’ table of income statement components by segment for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


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

													Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Other / Intersegment Eliminations		Ameren Illinois
Three Months 2023:	Three Months 2023:											Three Months 2023:
Electric revenues	Electric revenues	$	624	$	—	$	114	$	(28)	$	710	Electric revenues	$	540	$	—	$	113	$	(26)	627
Purchased power	Purchased power	(315)		—		—		28		(287)		Purchased power	(218)		—		—		26		(192)
Electric margins	Electric margins	309		—		114		—		423		Electric margins	322		—		113		—		435
Natural gas revenues	Natural gas revenues	—		391		—		—		391		Natural gas revenues	—		152		—		—		152
Natural gas purchased for resale	Natural gas purchased for resale	—		(161)		—		—		(161)		Natural gas purchased for resale	—		(33)		—		—		(33)
Natural gas margins	Natural gas margins	—		230		—		—		230		Natural gas margins	—		119		—		—		119
Other operations and maintenance expenses	Other operations and maintenance expenses	(129)		(59)		(14)		—		(202)		Other operations and maintenance expenses	(133)		(58)		(10)		—		(201)
Depreciation and amortization expenses	Depreciation and amortization expenses	(84)		(26)		(23)		—		(133)		Depreciation and amortization expenses	(87)		(27)		(24)		—		(138)
Taxes other than income taxes	Taxes other than income taxes	(18)		(23)		(1)		—		(42)		Taxes other than income taxes	(18)		(13)		(1)		—		(32)
Operating income (loss)	Operating income (loss)	78		122		76		—		276		Operating income (loss)	84		21		78		—		183
Other income, net	Other income, net	24		8		5		—		37		Other income, net	26		8		7		—		41
Interest charges	Interest charges	(21)		(13)		(13)		—		(47)		Interest charges	(22)		(13)		(15)		—		(50)
Income taxes	Income taxes	(20)		(30)		(18)		—		(68)		Income taxes	(21)		(5)		(18)		—		(44)

Net income												Net income	67		11		52		—		130
Preferred stock dividends												Preferred stock dividends	(1)		—		—		—		(1)
Net income attributable to common shareholder	Net income attributable to common shareholder	$	61	$	87	$	50	$	—	$	198	Net income attributable to common shareholder	$	66	$	11	$	52	$	—	$	129
Three Months 2022:	Three Months 2022:											Three Months 2022:
Electric revenues	Electric revenues	$	465	$	—	$	98	$	(20)	$	543	Electric revenues	504		$	—	$	105	$	(24)	585
Purchased power	Purchased power	(151)		—		—		20		(131)		Purchased power	(182)		—		—		24		(158)
Electric margins	Electric margins	314		—		98		—		412		Electric margins	322		—		105		—		427
Natural gas revenues	Natural gas revenues	—		481		—		—		481		Natural gas revenues	—		184		—		—		184
Natural gas purchased for resale	Natural gas purchased for resale	—		(247)		—		—		(247)		Natural gas purchased for resale	—		(68)		—		—		(68)
Natural gas margins	Natural gas margins	—		234		—		—		234		Natural gas margins	—		116		—		—		116
Other operations and maintenance expenses	Other operations and maintenance expenses	(147)		(63)		(13)		—		(223)		Other operations and maintenance expenses	(148)		(63)		(14)		—		(225)
Depreciation and amortization expenses	Depreciation and amortization expenses	(81)		(23)		(20)		—		(124)		Depreciation and amortization expenses	(82)		(25)		(21)		—		(128)
Taxes other than income taxes	Taxes other than income taxes	(20)		(31)		(2)		—		(53)		Taxes other than income taxes	(19)		(16)		—		—		(35)
Operating income (loss)	Operating income (loss)	66		117		63		—		246		Operating income (loss)	73		12		70		—		155
Other income, net	Other income, net	16		4		4		—		24		Other income, net	15		6		4		—		25
Interest charges	Interest charges	(18)		(11)		(13)		—		(42)		Interest charges	(18)		(11)		(12)		—		(41)
Income taxes	Income taxes	(15)		(30)		(14)		—		(59)		Income taxes	(18)		(1)		(16)		—		(35)

Net income												Net income	52		6		46		—		104
Preferred stock dividends												Preferred stock dividends	(1)		—		—		—		(1)
Net income attributable to common shareholder	Net income attributable to common shareholder	$	49	$	80	$	40	$	—	$	169	Net income attributable to common shareholder	$	51	$	6	$	46	$	—	$	103

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	Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Illinois Transmission		Other / Intersegment Eliminations		Ameren Illinois
Six Months 2023:
Electric revenues	$	1,164	$	—	$	227	$	(54)	$	1,337
Purchased power	(533)		—		—		54		(479)
Electric margins	631		—		227		—		858
Natural gas revenues	—		543		—		—		543
Natural gas purchased for resale	—		(194)		—		—		(194)
Natural gas margins	—		349		—		—		349
Other operations and maintenance expenses	(262)		(117)		(24)		—		(403)
Depreciation and amortization expenses	(171)		(53)		(47)		—		(271)
Taxes other than income taxes	(36)		(36)		(2)		—		(74)
Operating income (loss)	162		143		154		—		459
Other income, net	50		16		12		—		78
Interest charges	(43)		(26)		(28)		—		(97)
Income taxes	(41)		(35)		(36)		—		(112)
Net income	128		98		102		—		328
Preferred stock dividends	(1)		—		—		—		(1)
Net income attributable to common shareholder	$	127	$	98	$	102	$	—	$	327
Six Months 2022:
Electric revenues	$	969	$	—	$	203	$	(44)	$	1,128
Purchased power	(333)		—		—		44		(289)
Electric margins	636		—		203		—		839
Natural gas revenues	—		665		—		—		665
Natural gas purchased for resale	—		(315)		—		—		(315)
Natural gas margins	—		350		—		—		350
Other operations and maintenance expenses	(295)		(126)		(27)		—		(448)
Depreciation and amortization expenses	(163)		(48)		(41)		—		(252)
Taxes other than income taxes	(39)		(47)		(2)		—		(88)
Operating income (loss)	139		129		133		—		401
Other income, net	31		10		8		—		49
Interest charges	(36)		(22)		(25)		—		(83)
Income taxes	(33)		(31)		(30)		—		(94)
Net income	101		86		86		—		273
Preferred stock dividends	(1)		—		—		—		(1)
Net income attributable to common shareholder	$	100	$	86	$	86	$	—	$	272

Electric and Natural Gas Margins

Electric margins are defined as electric revenues less fuel and purchased power costs. Natural gas margins are defined as natural gas revenues less natural gas purchased for resale. We consider electric and natural gas margins useful measures to analyze the change in profitability of our electric and natural gas operations between periods. We have included the analysis below to complement the financial information we provide in accordance with GAAP. However, these margins may not be a presentation defined under GAAP, and they may not be comparable to other companies’ presentations or more useful than the GAAP information we provide elsewhere in this report.

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Electric Margins

Increase (Decrease) by Segment

Overall Ameren Decrease of $7 Million (QTD YoY)

Overall Ameren Increase of $10 Million (YTD YoY)

Total by Segment(a)

~~Overall Ameren Increase of $17 Million~~

(a)Includes other/intersegment eliminations of ~~$(10)~~$(7) million, $(6) million, $(17) million, and ~~$(7)~~$(13) million in the three months ended ~~March 31,~~June 30, 2023 and 2022, and six months ended June 30, 2023, and 2022, respectively.

Ameren Missouri

Ameren Illinois Electric Distribution

Ameren Transmission

Other/Intersegment Eliminations

Natural Gas Margins

Increase (Decrease) by Segment

~~Total by Segment~~Overall Ameren Change of $- Million (QTD YoY)~~(b)~~

Overall Ameren Decrease of $4 Million (YTD YoY)

Total by Segment(a)

~~(b)~~(a)Includes other/intersegment eliminations of $(1) million in the ~~three~~six months ended ~~March 31,~~June 30, 2023.

Ameren Missouri

Ameren Illinois Natural Gas

Other/Intersegment Eliminations

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The following tables present the favorable (unfavorable) variations by Ameren segment for electric and natural gas margins for the three and six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period:~~periods:


Electric and Natural Gas Margins	Electric and Natural Gas Margins													Electric and Natural Gas Margins
Three Months	Three Months	Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission(a)		Other /Intersegment Eliminations		Ameren		Three Months	Ameren Missouri		Ameren Illinois Electric Distribution		Ameren Illinois Natural Gas		Ameren Transmission(a)		Other /Intersegment Eliminations		Ameren
Electric revenue change:	Electric revenue change:													Electric revenue change:
Base rates (estimate)(b)	Base rates (estimate)(b)	$	38	$	(4)	$	—	$	17	$	—	$	51	Base rates (estimate)(b)	$	—	$	2	$	—	$	11	$	—	$	13
Effect of weather (estimate)(c)	Effect of weather (estimate)(c)	(33)		—		—		—		—		(33)		Effect of weather (estimate)(c)	(23)		—		—		—		—		(23)
Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)	Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)	(7)		—		—		—		—		(7)		Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)	(6)		—		—		—		—		(6)
Customer demand charges		2		—		—		—		—		2

Off-system sales, capacity, and FAC revenues, net	Off-system sales, capacity, and FAC revenues, net	90		—		—		—		—		90		Off-system sales, capacity, and FAC revenues, net	28		—		—		—		—		28
Ameren Illinois energy-efficiency program investment revenues	Ameren Illinois energy-efficiency program investment revenues	—		4		—		—		—		4		Ameren Illinois energy-efficiency program investment revenues	—		5		—		—		—		5
Other	Other	—		3		—		—		(3)		—		Other	(1)		(1)		—		—		(1)		(3)
Cost recovery mechanisms – offset in fuel and purchased power(d)	Cost recovery mechanisms – offset in fuel and purchased power(d)	12		164		—		—		(4)		172		Cost recovery mechanisms – offset in fuel and purchased power(d)	28		36		—		—		(2)		62
Other cost recovery mechanisms(e)	Other cost recovery mechanisms(e)	1		(8)		—		—		—		(7)		Other cost recovery mechanisms(e)	2		(6)		—		—		—		(4)
Total electric revenue change	Total electric revenue change	$	103	$	159	$	—	$	17	$	(7)	$	272	Total electric revenue change	$	28	$	36	$	—	$	11	$	(3)	$	72
Fuel and purchased power change:	Fuel and purchased power change:													Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather)	Energy costs (excluding the estimated effect of weather)	$	(90)	$	—	$	—	$	—	$	—	$	(90)	Energy costs (excluding the estimated effect of weather)	$	(22)	$	—	$	—	$	—	$	—	$	(22)
Effect of weather (estimate)(b)		7		—		—		—		—		7
Effect of higher net energy costs included in base rates		(1)		—		—		—		—		(1)
Effect of weather (estimate)(c)														Effect of weather (estimate)(c)	3		—		—		—		—		3

Other	Other	1		—		—		—		—		1		Other	2		—		—		—		—		2
Cost recovery mechanisms – offset in electric revenue(d)	Cost recovery mechanisms – offset in electric revenue(d)	(12)		(164)		—		—		4		(172)		Cost recovery mechanisms – offset in electric revenue(d)	(28)		(36)		—		—		2		(62)
Total fuel and purchased power change	Total fuel and purchased power change	$	(95)	$	(164)	$	—	$	—	$	4	$	(255)	Total fuel and purchased power change	$	(45)	$	(36)	$	—	$	—	$	2	$	(79)
Net change in electric margins	Net change in electric margins	$	8	$	(5)	$	—	$	17	$	(3)	$	17	Net change in electric margins	$	(17)	$	—	$	—	$	11	$	(1)	$	(7)
Natural gas revenue change:	Natural gas revenue change:													Natural gas revenue change:
Effect of weather (estimate)(b)		$	(9)	$	—	$	—	$	—	$	—	$	(9)
Base rates (estimate)		2		—		—		—		—		2
Effect of weather (estimate)(c)														Effect of weather (estimate)(c)	$	(1)	$	—	$	—	$	—	$	—	$	(1)
Sales volumes (excluding the estimated effect of weather)														Sales volumes (excluding the estimated effect of weather)	(2)		—		—		—		—		(2)
QIP	QIP	—		—		3		—		—		3		QIP	—		—		3		—		—		3
Other		—		—		—		—		(1)		(1)

Cost recovery mechanisms – offset in natural gas purchased for resale(d)	Cost recovery mechanisms – offset in natural gas purchased for resale(d)	9		—		(86)		—		—		(77)		Cost recovery mechanisms – offset in natural gas purchased for resale(d)	(2)		—		(35)		—		—		(37)
Other cost recovery mechanisms(e)	Other cost recovery mechanisms(e)	—		—		(7)		—		—		(7)		Other cost recovery mechanisms(e)	(1)		—		—		—		—		(1)
Total natural gas revenue change	Total natural gas revenue change	$	2	$	—	$	(90)	$	—	$	(1)	$	(89)	Total natural gas revenue change	$	(6)	$	—	$	(32)	$	—	$	—	$	(38)
Natural gas purchased for resale change:	Natural gas purchased for resale change:													Natural gas purchased for resale change:
Effect of weather (estimate)(b)		$	8	$	—	$	—	$	—	$	—	$	8
Effect of weather (estimate)(c)														Effect of weather (estimate)(c)	$	1	$	—	$	—	$	—	$	—	$	1
Cost recovery mechanisms – offset in natural gas revenue(d)	Cost recovery mechanisms – offset in natural gas revenue(d)	(9)		—		86		—		—		77		Cost recovery mechanisms – offset in natural gas revenue(d)	2		—		35		—		—		37
Total natural gas purchased for resale change	Total natural gas purchased for resale change	$	(1)	$	—	$	86	$	—	$	—	$	85	Total natural gas purchased for resale change	$	3	$	—	$	35	$	—	$	—	$	38
Net change in natural gas margins	Net change in natural gas margins	$	1	$	—	$	(4)	$	—	$	(1)	$	(4)	Net change in natural gas margins	$	(3)	$	—	$	3	$	—	$	—	$	—

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Electric and Natural Gas Margins
Six 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)	$	38	$	(2)	$	—	$	28	$	—	$	64
Effect of weather (estimate)(c)	(56)		—		—		—		—		(56)
Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)	(13)		—		—		—		—		(13)

Off-system sales, capacity, and FAC revenues, net	118		—		—		—		—		118
Ameren Illinois energy-efficiency program investment revenues	—		9		—		—		—		9
Other	1		2		—		—		(4)		(1)
Cost recovery mechanisms – offset in fuel and purchased power(d)	40		200		—		—		(6)		234
Other cost recovery mechanisms(e)	3		(14)		—		—		—		(11)
Total electric revenue change	$	131	$	195	$	—	$	28	$	(10)	$	344
Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather)	$	(112)	$	—	$	—	$	—	$	—	$	(112)
Effect of weather (estimate)(c)	10		—		—		—		—		10
Effect of higher net energy costs included in base rates	(1)		—		—		—		—		(1)
Other	3		—		—		—		—		3
Cost recovery mechanisms – offset in electric revenue(d)	(40)		(200)		—		—		6		(234)
Total fuel and purchased power change	$	(140)	$	(200)	$	—	$	—	$	6	$	(334)
Net change in electric margins	$	(9)	$	(5)	$	—	$	28	$	(4)	$	10
Natural gas revenue change:
Effect of weather (estimate)(c)	$	(10)	$	—	$	—	$	—	$	—	$	(10)
Sales volumes (excluding the estimated effect of weather)	(2)		—		—		—		—		(2)
QIP	—		—		6		—		—		6
Other	2		—		—		—		(1)		1
Cost recovery mechanisms – offset in natural gas purchased for resale(d)	7		—		(121)		—		—		(114)
Other cost recovery mechanisms(e)	(1)		—		(7)		—		—		(8)
Total natural gas revenue change	$	(4)	$	—	$	(122)	$	—	$	(1)	$	(127)
Natural gas purchased for resale change:
Effect of weather (estimate)(c)	$	9	$	—	$	—	$	—	$	—	$	9
Cost recovery mechanisms – offset in natural gas revenue(d)	(7)		—		121		—		—		114
Total natural gas purchased for resale change	$	2	$	—	$	121	$	—	$	—	$	123
Net change in natural gas margins	$	(2)	$	—	$	(1)	$	—	$	(1)	$	(4)

(a)Includes an increase in transmission margins of ~~$16~~$8 million and $24 million at Ameren Illinois for the three and six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period.~~periods.

(b)For Ameren Illinois Electric Distribution and Ameren Transmission, base rates include increases or decreases to operating revenues related to the revenue requirement reconciliation adjustment under formula rates. For Ameren Missouri, base rates exclude an increase for the recovery of lost electric margins resulting from the MEEIA customer energy-efficiency programs and a decrease in base rates for RESRAM. These changes in Ameren Missouri base rates are included in the “Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)” and “Cost recovery mechanisms - offset in fuel and purchased power” line items, respectively.

(c)Represents the estimated variation resulting primarily from changes in cooling and heating degree-days on electric and natural gas demand compared with the year-ago ~~period;~~periods; this variation is based on temperature readings from the National Oceanic and Atmospheric Administration weather stations at local airports in our service territories.

(d)Electric and natural gas revenue changes are offset by corresponding changes in “Fuel,” “Purchased power,” and “Natural gas purchased for resale” on the statement of income, resulting in no change to electric and natural gas margins. Activity in Other/Intersegment Eliminations represents the elimination of related-party transactions between Ameren Missouri, Ameren Illinois, and ATXI, as well as Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution. See Note 8 – Related-party Transactions and Note 14 – Segment Information under Part I, Item 1, of this report for additional information on intersegment eliminations.

(e)Offsetting expense increases or decreases are reflected in “Other operations and maintenance,” “Depreciation and amortization,” or in “Taxes other than income taxes,” within the “Operating Expenses” section and "Income Taxes" in the statement of income. These items have no overall impact on earnings.

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Ameren

Ameren’s electric margins ~~increased $17~~decreased $7 million, or 2%1%, for the three months ended ~~March 31,~~June 30, 2023, compared with the year-ago period, due to decreased margins at Ameren Missouri, partially offset by increased margins at Ameren Transmission, as discussed below. Ameren’s electric margins increased $10 million, or less than 1%, for the six months ended June 30, 2023, compared with the year-ago period, due to increased margins at Ameren Transmission, ~~and Ameren Missouri,~~ partially offset by decreased margins at Ameren Missouri and Ameren Illinois Electric Distribution, as discussed below. Ameren’s natural gas margins were comparable for the three months ended June 30, 2023, and decreased $4 million, or 1%, for the ~~three~~six months ended ~~March 31,~~June 30, 2023, compared with the year-ago period, due to decreased margins at Ameren Missouri Natural Gas and Ameren Illinois Natural Gas, as discussed below.

Ameren Transmission

Ameren Transmission’s margins increased ~~$17~~$11 million, or ~~12%~~7%, and $28 million, or 9%, for the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period.~~periods. Base rate revenues were favorably affected primarily by higher recoverable expenses (+$~~11 million)~~5 million and +$16 million, respectively) and increased capital investment (+$6 ~~million)~~million and +$13 million, respectively), as evidenced by an 11% increase in rate base used to calculate the revenue requirement.

Ameren Missouri

Ameren Missouri’s electric margins ~~increased $8~~decreased $17 million, or 2%3%, and $9 million, or 1%, for the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period.~~periods. Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” increased ~~$12~~$28 million and $40 million for the three and six months ended ~~March 31,~~June 30, 2023, respectively, due to ~~changes in~~increased revenue related to the amortization of costs previously deferred under the FAC that were reflected in customer ~~rates.~~rates, which also increased fuel expense. The changes to “Cost recovery mechanisms - offset in fuel and purchased power” are fully offset by “Cost recovery mechanisms - offset in electric revenue,” in the table above, and result in no impact to margins. Ameren Missouri’s 5% exposure to net energy cost variances under the FAC is reflected within “Off-system sales, capacity, and FAC revenues, net” and “Energy costs (excluding the estimated effect of weather)”,~~” which was comparable between periods.~~ as discussed below.

The following items had an unfavorable effect on Ameren Missouri’s electric margins for the three and six months ended June 30, 2023, compared with the year-ago periods (except where a specific period is referenced):

•Summer temperatures were milder as cooling degree days decreased 15% for the three months ended June 30, 2023, and winter temperatures were warmer as heating degree days decreased 19% for the six months ended June 30, 2023. The aggregate effect of weather decreased margins an estimated $20 million and $46 million for the three and six months ended June 30, 2023, respectively. The change in ~~net energy costs~~margins due to weather is the sum of ~~“Off-system sales, capacity~~the “Effect of weather (estimate)” on electric revenues (-$23 million and ~~FAC revenues, net”~~-$56 million, respectively) and the “Effect of weather (estimate)” on fuel and purchased power (+$~~90 million)~~3 million and ~~“Energy costs (excluding the estimated effect of weather)” (-$90 million)~~+$10 million, respectively) in the table above. In

•Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues decreased an estimated $6 million and $13 million for the three and six months ended ~~March 31,~~June 30, 2023, ~~these revenues and costs increased~~respectively. These decreases were primarily due to ~~higher capacity prices, partially offset by the effect of decreased generation volumes.~~ ~~Ameren Missouri sells nearly all of its capacity to the MISO and purchases the capacity it needs to supply its native load sales from the MISO.~~ C~~apacity revenues increased $154 million and capacity costs increased $149 million. Capacity~~ revenues and costs increased as the capacity price set by the annual MISO auction in 2022 increased from $5 per MW-day to $237 per MW-day. The April 2021 MISO auction pricing was effective from June 2021 through May 2022, while the April 2022 MISO auction pricing established the annual rate beginning in June 2022. See Outlook for additional information related to the April 2022 MISO auction. These increases in capacity revenues and costs were partially offset by the effect of lower market prices for power, which resulted in a decrease in ~~off-system~~retail sales volumes and a decrease in the average retail price per kilowatthour related ~~fuel costs.~~to changes in customer usage patterns.

The following items had a favorable effect on Ameren Missouri’s electric margins for the three and six months ended June 30, 2023, compared with the year-ago periods:

•Higher electric base rates, excluding the change in base rates for the MEEIA customer energy-efficiency programs and the RESRAM, resulting from the December 2021 MoPSC electric rate order effective February 28, 2022, partially offset by higher net energy costs included in base rates, increased margins an estimated $37 million for the ~~three~~six months ended ~~March 31,~~June 30, 2023. The change in electric base rates is the sum of the change in “Base rates (estimate)” (+$38 million) and the “Effect of higher net energy costs included in base rates” (-$1 million) in the table above.

~~The following items had an unfavorable effect on Ameren Missouri’s electric margins between periods:~~

•~~Winter temperatures were warmer as heating degree days decreased 18% for~~Ameren Missouri’s 5% exposure to net energy cost variances under the ~~three months ended March 31, 2023. The aggregate effect of weather decreased~~FAC increased margins ~~an estimated $26~~$6 million for the three and six months ended ~~March 31,~~June 30, 2023. The change in ~~margins due to weather~~net energy costs is the sum of “Off-system sales, capacity and FAC revenues, net” (+$28 million and +$118 million, respectively) and “Energy costs (excluding the ~~“Effect~~estimated effect of ~~weather (estimate)~~weather)” ~~on electric~~(-$22 million and -$112 million, respectively) in the table above. In the three and six months ended June 30, 2023, these revenues ~~(-$33 million)~~ and costs increased primarily due to higher capacity prices, partially offset by the ~~“Effect~~effect of ~~weather (estimate)” on~~decreased generation volumes and lower market prices for power. Ameren Missouri sells nearly all of its capacity to the MISO and purchases the capacity it needs to supply its native load sales from the MISO. For the three and six months ended June 30, 2023, capacity revenues increased $54 million and $209 million, respectively, and capacity costs increased $52 million and $201 million, respectively. Capacity revenues and costs increased due to an increase in the price set by the annual MISO auction in April 2022, which became effective June 2022. These increases in capacity revenues and costs were partially offset by lower capacity prices set by the annual MISO auction in April 2023, which became effective June 2023, as well as the

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effect of lower market prices for power, which resulted in a decrease in off-system sales and related fuel costs. See Outlook for additional information related to the April 2022 and April 2023 MISO auctions.

•Other cost recovery mechanisms increased margins $3 million for the six months ended June 30, 2023, primarily due to an increase in recoverable MEEIA program costs.

•Other decreases in fuel and purchased power ~~(+$7 million) in~~expenses, which increased margins $3 million for the ~~table above.~~

•~~Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues decreased an estimated $7 million. This was primarily~~six months ended June 30, 2023, were largely due to a decrease in ~~retail sales volumes and a decrease in the average retail price per kilowatthour related to changes in customer usage patterns.~~transmission network upgrade charges.

Ameren Missouri’s natural gas margins decreased $3 million, or 18%, for the three months ended June 30, 2023, and were comparable ~~between periods.~~for the six months ended June 30, 2023. Margins decreased for the three months ended June 30, 2023, due primarily to lower sales volume from residential customers. Purchased gas costs increased $9$7 million for the ~~three~~six months ended ~~March 31,~~June 30, 2023, due to amortization of natural gas costs previously deferred under the PGA, driven by a significant increase in cost and customer demand as result of the extremely cold weather in mid-February 2021. The increased purchased natural gas costs are fully offset by an increase in natural gas revenues under the PGA, resulting in no impact to margin. The increase in purchased natural gas cost is reflected in “Cost recovery mechanisms – offset in natural gas revenue” and the associated recoverability from customers is reflected in “Cost recovery mechanisms – offset in natural gas purchased for resale” in the table above.

Ameren Illinois

Ameren Illinois’ electric margins increased ~~$11~~$8 million, or 3%2%, and $19 million, or 2%, for the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period,~~periods, driven by increased margins at Ameren Illinois Transmission, partially offset by decreased margins at Ameren Illinois Electric ~~Distribution.~~Distribution for the six months ended June 30, 2023. Ameren Illinois Natural Gas’ margins ~~decreased $4~~increased $3 million, or 2%3%, for the three months ended ~~March 31,~~June 30, 2023 ~~compared with~~

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, and were comparable for the ~~year-ago period.~~six months ended June 30, 2023.

Ameren Illinois Electric Distribution

Ameren Illinois Electric Distribution’s margins were comparable for the three months ended June 30, 2023, and decreased $5 million, or 2%1%, for the ~~three~~six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period.~~periods. Purchased power costs increased ~~$164~~$36 million and $200 million for the three and six months ended ~~March 31,~~June 30, 2023, respectively, primarily due to increased energy prices (+$~~97 million)~~1 million and +$96 million, respectively) largely reflecting the results of IPA procurement events, and increased capacity prices (+$~~44 million)~~19 million and +$63 million, respectively). In the three and six months ended ~~March 31,~~June 30, 2023, capacity revenues and costs increased asdue to an increase in the ~~capacity~~ price set by the annual MISO auction in April 2022, ~~increased from $5 per MW-day to $237 per MW-day. The April 2021~~which became effective June 2022. These increases in capacity revenues and costs were partially offset by lower capacity prices set by the annual MISO auction ~~pricing was~~in April 2023, which became effective ~~from~~ June ~~2021 through May 2022, while the April 2022 MISO auction pricing established the annual rate beginning in June 2022.~~2023. See Outlook for additional information related to the April 2022 and April 2023 MISO ~~auction.~~auctions. In addition to increased energy and capacity prices, higher volumes increased purchased power costs (+$~~17 million)~~13 million and +$31 million, respectively), primarily due to residential and small commercial customer switching from alternative retail electric suppliers to Ameren Illinois’ supplied power. The increased purchased power costs are fully offset by an increase in electric revenues under the cost recovery mechanisms for purchased power, resulting in no impact to margin. The increase in purchased power cost is reflected in “Cost recovery mechanisms – offset in electric revenue” and the associated recoverability from customers is reflected in “Cost recovery mechanisms – offset in fuel and purchased power” in the table above.

~~The following items had an unfavorable effect on Ameren Illinois Electric Distribution’s margins between periods:~~

•Other cost recovery mechanisms decreased margins by $8$6 million and $14 million for the three and six months ended June 30, 2023, respectively, compared with the year-ago periods, primarily due to a lower amount of bad debt costs included in customer rates pursuant to the associated rider.

•~~Base rates~~ The decreased margins were partially offset by $4an increase in revenues of $5 million and $9 million, respectively, due to the recovery of and return on increased energy-efficiency program investments under performance-based formula ratemaking. The impact from base rates was comparable (+$2 million and -$2 million, respectively) due to lower recoverable non-purchased power expenses (-$~~13 million)~~3 million and -$16 million, respectively), ~~partially~~ offset by a higher recognized ROE (+$~~6 million)~~2 million and +$8 million, respectively), as evidenced by an increase of ~~115~~74 basis points in the estimated annual average of the monthly yields of the 30-year United States Treasury bonds, and increased capital investment (+$3 ~~million)~~million and +$6 million, respectively), as evidenced by ~~an 8%~~a 7% increase in rate base used to calculate the revenue requirement.

For the three months ended March 31, 2023, revenues increased $4 million due to the recovery of and return on increased energy-efficiency program investments under performance-based formula ratemaking.

Ameren Illinois Natural Gas

Ameren Illinois Natural Gas’ margins ~~decreased $4~~increased $3 million, or 2%3%, for the three months ended ~~March 31,~~June 30, 2023, ~~compared with~~and were comparable for the ~~year-ago period.~~six months ended June 30, 2023. Purchased gas costs decreased ~~$86~~$35 million and $121 million for the three and six months ended ~~March 31,~~June 30, 2023, respectively, primarily due to lower amortization of natural gas costs that were previously deferred under the PGA and lower natural gas prices in 2023. Those deferred natural gas costs related to the mid-February 2021 weather event were fully recovered from customers by the end of 2022. The decreased purchased natural gas costs are fully offset by a decrease in natural gas revenues under the PGA, resulting in no impact to margin. The decrease in purchased natural gas cost is reflected in “Cost recovery mechanisms – offset in natural gas revenue” and the associated recoverability from customers is reflected in “Cost recovery mechanisms – offset in natural gas purchased for resale” in the table above. ~~Other cost recovery mechanisms decreased revenues $7 million for the three months ended March 31, 2023, primarily due to decreased revenues for excise taxes.~~ Revenues increased $3 million and $6 million due to additional investment in natural gas infrastructure under the QIP for the three and six months ended ~~March 31, 2023.~~June 30, 2023, respectively. Other cost recovery mechanisms decreased

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revenues $7 million for the six months ended June 30, 2023, primarily due to decreased revenues for excise taxes.

Ameren Illinois Transmission

Ameren Illinois Transmission’s margins increased ~~$16~~$8 million, or ~~16%~~8%, and $24 million, or 12%, for the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period.~~periods. Base rate revenues were favorably affected primarily by ~~higher recoverable expenses (+$9 million) and~~ increased capital investment (+$~~7 million)~~6 million and +$13 million, respectively), as evidenced by a 17% increase in rate base used to calculate the revenue requir~~ement.~~ement, and higher recoverable expenses (+$3 million and +$12 million, respectively).

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Other Operations and Maintenance Expenses

Increase (Decrease) by Segment

Overall Ameren Decrease of $41 Million (QTD YoY)

Overall Ameren Decrease of $54 Million (YTD YoY)

Total by Segment(a)

~~Overall Ameren Decrease of $13 Million~~

(a)Includes $13 million and $16 million at Ameren Transmission in the three months ended June 30, 2023 and 2022, respectively. Includes other/intersegment eliminations of $5$9 million and $3$4 million in the three months ended ~~March 31,~~June 30, 2023 and 2022, respectively. Also includes other/intersegment eliminations of $14 million and $7 million in the six months ended June 30, 2023 and 2022, respectively.

Ameren Missouri

Ameren Illinois Natural Gas

Other/Intersegment Eliminations

Ameren Illinois Electric Distribution

Ameren Transmission

Ameren

Other operations and maintenance expenses decreased ~~$13~~$41 million and $54 million in the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period, due~~periods. In addition to changes by segments discussed ~~below.~~below, other operations and maintenance expenses increased $5 million and $7 million in the three and six months ended June 30, 2023, respectively, for activity not reported as part of a segment, as reflected in “Other/Intersegment Eliminations” above, primarily because of an increase in the elimination of the non-service cost component of net periodic benefit income at Ameren Services. 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 ~~were comparable between~~decreased $3 million in both the three and six months ended June 30, 2023, compared with the year-ago periods, primarily because of increases in the cash surrender value of COLI due to favorable market returns in 2023, compared with unfavorable market returns in the year-ago periods.

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Ameren Missouri

Other operations and maintenance expenses ~~increased $7~~decreased $23 million and $16 million in the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago periods. The following items decreased other operations and maintenance expenses in the three and six months ended June 30, 2023, compared with the year-ago periods (except where a specific period ~~primarily due~~is referenced):

•The cash surrender value of COLI increased $10 million and $19 million, respectively. In the three and six months ended June 30, 2023, the effect of changes in the cash surrender value of COLI resulted in gains of $2 million and $5 million, respectively, compared with losses of $8 million and $14 million, respectively, in the year-ago periods.

•The recognition of regulatory assets for previously expensed costs approved for recovery pursuant to the ~~following items:~~June 2023 MoPSC rate order decreased other operations and maintenance expenses $15 million in both periods.

•Renewable development costs decreased $6 million and $9 million, respectively, as the MoPSC order approving CCNs for the Boomtown and Huck Finn solar projects in the first half of 2023 led to increased capitalization of renewable development costs pursuant to anticipated recovery from customers.

•Energy center operating and maintenance costs decreased $2 million and $5 million, respectively, related to the retirement of the Meramec Energy Center.

The above decreases in the three and six months ended June 30, 2023, compared with the year-ago periods, were partially offset by the below items (except where a specific period is referenced):

•Labor and benefit costs increased $6$5 million and $11 million, respectively, primarily because of increased medical and retirement benefits, including the effect of a higher base level of pension service costs reflected in electric service rates effective February 28, 2022, pursuant to the December 2021 MoPSC rate ~~order.~~order for the six months ended June 30, 2023. Pursuant to the pension tracker, differences between actual costs incurred and base level expenses included in customer rates are deferred as a regulatory asset or liability for recovery from, or refund to, customers over a period of time as determined in a subsequent regulatory rate review.

•~~Transmission~~Callaway Energy Center costs increased $2 million and ~~distribution expenditures increased~~ $5 million, respectively, primarily because of ~~timing~~the amortization of ~~system~~increased costs related to the spring 2022 refueling and maintenance ~~expenditures.~~outage, which costs began amortizing in June 2022.

•MEEIA customer energy-efficiency program spend increased $4 million in the six months ended June 30, 2023, as approved by the MoPSC.

The above increases were partially offset by a $9 million increase in the cash surrender value of COLI. In the three months ended March 31, 2023, the effect of changes in the cash surrender value of COLI was a gain of $3 million, compared with a loss of $6•Costs for injuries and damages increased $4 million in the six months ended June 30, 2023, primarily because of an increase in claims, compared with the year-ago period.

•Technology-related expenditures increased $3 million in the six months ended June 30, 2023, resulting from increased software maintenance expenses.

Ameren Illinois

Other operations and maintenance expenses decreased ~~$21~~$24 million and $45 million in the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago ~~period,~~periods, as discussed below. Other operations and maintenance expenses ~~were comparable~~decreased $4 million and $3 million at Ameren Illinois Transmission ~~between~~in the three and six months ended June 30, 2023, respectively, compared with the year-ago periods, primarily because of increases in the cash surrender value of COLI due to favorable market returns in 2023, compared with unfavorable market returns in the year-ago periods.

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Ameren Illinois Electric Distribution

Other operations and maintenance expenses decreased ~~$18~~$15 million and $33 million in the three and six months ended ~~March 31,~~June 30, 2023, respectively, compared with the year-ago periods. The following items decreased other operations and maintenance expenses in the three and six months ended June 30, 2023, compared with the year-ago periods (except where a specific period ~~primarily because of the following items:~~is referenced):

•Bad debt costs decreased ~~$13~~$10 million ~~due to~~and $23 million, respectively, because of a lower amount of costs included in customer rates pursuant to the associated rider.

•~~Distribution system expenditures decreased $7 million, primarily because of disciplined cost management and timing of vegetation management expenses.~~

•The cash surrender value of COLI increased $4$5 million and $9 million, respectively, primarily because of favorable market returns in 2023, compared with unfavorable market returns in the year-ago ~~period.~~periods.

•Costs for injuries and damages decreased $4 million in both periods, primarily because of a decrease in claims compared with the year-ago periods.

The above decreases in the three and six months ended June 30, 2023, compared with the year-ago periods, were partially offset by ~~a $3~~increases of $2 million ~~increase~~and $4 million, respectively, in the amortization of regulatory assets associated with customer energy-efficiency program investments under formula ratemaking.

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Ameren Illinois Natural Gas

Other operations and maintenance expenses decreased $4$5 million and $9 million in the three and six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period,~~periods, primarily because ~~of a $2 million increase in~~ the cash surrender value of ~~COLI.~~COLI increased $3 million and $5 million, respectively. In the three and six months ended ~~March 31,~~June 30, 2023, the effect of changes in the cash surrender value of COLI ~~was a gain of $1 million, compared with a loss~~resulted in gains of $1 million in both periods, compared with losses of $2 million and $4 million, respectively, in the year-ago ~~period.~~periods. Other operations and maintenance expenses also decreased $2 million and $4 million, respectively, because of decreased distribution system expenditures, primarily because of the timing of expenditures.

Depreciation and Amortization Expenses

Increase by Segment

Overall Ameren Increase of $19 Million (QTD YoY)

Overall Ameren Increase of $40 Million (YTD YoY)

Total by Segment(a)

~~Overall Ameren Increase of $21 Million~~

(a)Includes other/intersegment eliminations of $1 million and $1 million in the three months ended ~~March 31,~~June 30, 2023 and 2022, respectively. Also includes other/intersegment eliminations of $2 million and $2 million in the six months ended June 30, 2023 and 2022, ~~respectively.~~respectively..

Ameren Missouri

Ameren Illinois Natural Gas

Other/Intersegment Eliminations

Ameren Illinois Electric Distribution

Ameren Transmission

Depreciation and amortization expenses increased ~~$21~~$19 million, ~~$12~~$8 million, and $9$10 million in the three months ended ~~March 31,~~June 30, 2023, and $40 million, $20 million, and $19 million in the six months ended June 30, 2023, compared with the year-ago ~~period,~~periods, at Ameren, Ameren Missouri, and Ameren Illinois, respectively, primarily because of additional property, plant, and equipment investments across their respective segments. Ameren’s and Ameren Missouri’s depreciation and amortization expenses for the three and six months ended ~~March 31,~~June 30, 2023, compared with the year-ago ~~period,~~periods, were affected by the following (except where a specific period is referenced), which include the effect of the additional investments at Ameren Missouri:

•Depreciation and amortization rate changes effective February 28, 2022, pursuant to the December 2021 MoPSC electric rate order, which increased depreciation and amortization expenses by $11 ~~million.~~million, in the six months ended June 30, 2023.

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•Increased depreciation and amortization expenses of $11 million for amounts previously deferred under the PISA and RESRAM and subsequently reflected in base rates effective February 28, 2022, pursuant to the December 2021 MoPSC electric rate order, largely due to investments in wind ~~generation.~~

•~~The absence~~generation, in ~~2023 of 2022 deferrals and increased amortization of Meramec Energy Center retirement costs increased depreciation and amortization expenses by $8 million pursuant to~~ the ~~December 2021 MoPSC electric rate order, which established a five-year recovery period for certain Meramec Energy Center costs beginning February 28, 2022.~~six months ended June 30, 2023.

•Depreciation and amortization expenses at Ameren and Ameren Missouri reflected a deferral to a regulatory asset of depreciation and amortization expenses pursuant to PISA and RESRAM. The amount of depreciation and amortization expenses included in base rates for PISA and RESRAM deferrals was updated when new customer rates became effective on February 28, 2022, pursuant to the December 2021 MoPSC electric rate order, which incorporated deferrals through September 30, 2021. ~~Lower~~The effect of deferrals ~~due to the inclusion in base rates of~~and increased depreciation and amortization ~~associated with certain property, plant,~~expenses, primarily because of electric system capital additions, increased depreciation

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$3 million and ~~equipment previously deferred under the PISA and~~$11 million, respectively.

•The lower net under-recovery of RESRAM eligible expenses increased depreciation and amortization expenses by ~~$8 million.~~

•~~The retirement of~~$2 million in the ~~Meramec Energy Center in December 2022, which decreased depreciation and amortization expenses by $14 million.~~

•~~The~~three months ended June 30, 2023, while the higher net under-recovery of RESRAM eligible expenses decreased depreciation and amortization expenses by ~~$13 million.~~$11 million in the six months ended June 30, 2023.

•The impact of the retirement of the Meramec Energy Center in December 2022 resulted in a $3 million increase to depreciation and amortization expenses in the three months ended June 30, 2023, and a $3 million decrease in the six months ended June 30, 2023, primarily due to the deferral in 2022 of the energy center’s depreciation and amortization expenses and resulting amortization of that deferral pursuant to the December 2021 MoPSC electric rate order, which established a five-year recovery period for certain Meramec Energy Center costs beginning February 28, 2022.

Taxes Other Than Income Taxes

Increase (Decrease) by Segment

Overall Ameren Decrease of $5 Million (QTD YoY)

Overall Ameren Decrease of $20 Million (YTD YoY)

Total by Segment(a)

~~Overall Ameren Decrease of $15 Million~~

(a)Includes $2 million, $2 million, $4 million, and $2$4 million at Ameren Transmission in the three months ended ~~March 31,~~June 30, 2023 and 2022, ~~respectively,~~ and in the six months ended June 30, 2023 and 2022, respectively. Also includes other/intersegment eliminations of $4$3 million, $2 million, $7 million, and $4$6 million in the three months ended ~~March 31,~~June 30, 2023 and 2022, and in the six months ended June 30, 2023 and 2022, respectively.

Ameren Missouri

Ameren Illinois Natural Gas

Other/Intersegment Eliminations

Ameren Illinois Electric Distribution

Ameren Transmission

Taxes other than income taxes decreased ~~$15~~$5 million in the three months ended ~~March 31,~~June 30, 2023, compared with the year-ago period, primarily because of decreased sales at Ameren Illinois Natural Gas and deferral of taxes under the Ameren Missouri electric property tax tracker. Taxes other than income taxes decreased $20 million in the six months ended June 30, 2023, compared with the year-ago period, primarily because of a $7$9 million decrease in excise taxes at Ameren Illinois Natural Gas, primarily resulting from decreased sales. Taxes other than income ~~taxes~~ also decreased $5 million and $2 million at Ameren Missouri and Ameren Illinois Electric Distribution, respectively, because of employee retention tax credits received under the Coronavirus Aid, Relief, and Economic Security Act.

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Other Income, Net

Increase (Decrease) by Segment

Overall Ameren Increase of $20 Million (QTD YoY)

Overall Ameren Increase of $38 Million (YTD YoY)

Total by Segment(a)

~~Overall Ameren Increase of $18 Million~~

(a)Includes $8 million and $4 million at Ameren Transmission in the three months ended June 30, 2023 and 2022, respectively.

Ameren Missouri

Ameren Illinois Natural Gas

Other/Intersegment Eliminations

Ameren Illinois Electric Distribution

Ameren Transmission

Other income, net, increased ~~$18~~$20 million in the three months ended ~~March 31,~~June 30, 2023, compared with the year-ago period, primarily because of increases in the non-service cost component of net periodic benefit income of $8$7 million, $7$6 million, and $3 million for activity not reported as part of a segment, Ameren Illinois Electric Distribution, and Ameren Illinois Natural Gas, respectively. ~~Other~~In the three months ended June 30, 2023, other income, net, also increased $4 million because of ahigher interest income on under-recovered balances associated with regulatory recovery mechanisms at Ameren Illinois Electric Distribution and $2 million ~~increase in the equity portion~~because of higher allowance for equity funds used during construction ~~for~~at Ameren Transmission. ~~These~~Other income, net, increased $38 million in the six months ended June 30, 2023, compared with the year-ago period, primarily because of increases in the non-service cost component of net periodic benefit income of $15 million, $13 million, and $6 million for activity not reported as part of a segment, Ameren Illinois Electric Distribution, and Ameren Illinois Natural Gas, respectively. In the six months ended June 30, 2023, other income, net, also increased $7 million because of higher interest income on under-recovered balances associated with regulatory recovery mechanisms at Ameren Illinois Electric Distribution and $4 million because of higher allowance for equity funds used during construction at Ameren Transmission. The increases in other income, net, in the three and six months ended June 30, 2023, were partially offset by ~~a $5~~$6 million ~~decrease~~and $11 million decreases, respectively, in interest income on industrial development revenue bonds at Ameren Missouri, as these bonds were settled in December 2022 and January 2023. The increases in other income, net, associated with these bonds are offset by decreases in interest charges on a related financing obligation agreement, as discussed below.

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.

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Interest Charges

Increase (Decrease) by Segment

Overall Ameren Increase of $8 Million (QTD YoY)

Overall Ameren Increase of $31 Million (YTD YoY)

Total by Segment

~~Overall Ameren Increase of $23 Million~~

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. See Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for additional information on the termination of the financing obligation agreement discussed below.

Ameren

Interest charges increased ~~$23~~$8 million and $31 million in the three and six months ended June 30, 2023, compared with the year-ago periods. In addition to changes by segments discussed below, interest charges increased $8 million and $14 million, respectively, at Ameren (parent) because of higher interest rates on increased levels of short-term borrowings.

Ameren Missouri

Interest charges decreased $8 million in the three months ended ~~March 31,~~June 30, 2023, and increased $4 million in the six months ended June 30, 2023, compared with the year-ago periods. The following items increased interest charges in the three and six months ended June 30, 2023, compared with the year-ago periods (except where a specific period ~~primarily because of the following items:~~is referenced):

•Interest charges ~~at Ameren~~increased $3 million and ~~Ameren Missouri~~$8 million, respectively, because of higher interest rates on increased levels of short-term borrowings.

•Issuances of long-term debt in April 2022 and March 2023 collectively increased interest charges by $7 million and $13 million, respectively.

•Interest charges reflected a deferral to a regulatory asset of interest charges pursuant to PISA and RESRAM. The amount of interest charges included in base rates for PISA and RESRAM deferrals was updated when new customer rates became effective on February 28, 2022, pursuant to the December 2021 MoPSC electric rate order, which incorporated deferrals through September 30, 2021. Lower deferrals, due to 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 ~~$9 million.~~$2 million in the six months ended June 30, 2023.

•~~Issuances~~Table of ~~long-term debt at Ameren Missouri in April 2022 and March 2023 collectively increased interest charges by $6 million.~~Contents

•~~Interest charges increased $6 million and $5 million at Ameren (parent) and Ameren Missouri, respectively, because of higher interest rates on increased levels of short-term borrowings.~~

•~~Issuances of long-term debt at Ameren Illinois Electric Distribution in August and November 2022 collectively increased interest charges by $4 million.~~

The following items ~~partially offset~~decreased interest charges in the ~~above increases in interest charges:~~three and six months ended June 30, 2023 (except where a specific period is referenced):

•~~Interest~~Increased PISA and RESRAM deferrals reduced interest charges ~~decreased $5~~by $7 million ~~at Ameren Missouri because of an increase~~ in the ~~allowance for borrowed funds, primarily due to increased eligible construction work in process balances and a higher applicable borrowing rate.~~three months ended June 30, 2023.

•Interest charges decreased $5$6 million ~~at Ameren Missouri,~~and $11 million, respectively, primarily due to the termination of a financing obligation agreement related to the CT energy center in Audrain County.

~~See Note 3 – Short-term Debt~~•Interest charges decreased $4 million and ~~Liquidity under Part I, Item 1,~~$9 million, respectively, because of ~~this report~~an increase in the borrowed funds capitalized as part of the allowance for funds used during construction, primarily due to increased eligible construction work in process balances and a higher applicable borrowing rate.

Ameren Illinois

Interest charges increased $9 million and $14 million in the ~~Long-term Debt~~three and ~~Equity section below for additional information on short-term borrowings and~~six months ended June 30, 2023, compared with the year-ago periods, primarily due to the issuances of long-term debt ~~respectively. See Note 4 – Long-term Debt~~in 2022. Issuances of long-term debt at Ameren Illinois in August and ~~Equity Financings under Part I, Item 1, of this report for additional information on the termination of the financing obligation agreement.~~

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November 2022 collectively increased interest charges by $4 million and $8 million, respectively, at Ameren Illinois Electric Distribution, by $3 million and $6 million, respectively, at Ameren Illinois Transmission, and by $2 million and $4 million, respectively, at Ameren Illinois Natural Gas.

Income Taxes

The following table presents effective income tax rates for the three and six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months(a)				Three Months(a)				Six Months(a)
			2023		2022			2023		2022		2023		2022
Ameren	Ameren		12	%	12	%	Ameren	14	%	15	%	13	%	13	%
Ameren Missouri	Ameren Missouri		(4)	%	(4)	%	Ameren Missouri	(1)	%	(2)	%	(1)	%	(3)	%
Ameren Illinois	Ameren Illinois		25	%	26	%	Ameren Illinois	25	%	25	%	25	%	26	%
Ameren Illinois Electric Distribution	Ameren Illinois Electric Distribution		24	%	24	%	Ameren Illinois Electric Distribution	25	%	26	%	25	%	25	%
Ameren Illinois Natural Gas	Ameren Illinois Natural Gas		26	%	27	%	Ameren Illinois Natural Gas	27	%	25	%	26	%	27	%
Ameren Illinois Transmission	Ameren Illinois Transmission		26	%	26	%	Ameren Illinois Transmission	26	%	25	%	26	%	26	%
Ameren Transmission	Ameren Transmission		26	%	27	%	Ameren Transmission	26	%	26	%	26	%	26	%

(a)Estimate of the annual effective income tax rate adjusted to reflect the tax effect of items discrete to the three and six months ended ~~March 31,~~June 30, 2023 and 2022.

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 income tax rate was higher at Ameren Illinois Natural Gas in the three months ended June 30, 2023, compared with the year-ago period, primarily because of higher depreciation differences on property-related items.

LIQUIDITY AND CAPITAL RESOURCES

Collections from our tariff-based revenues are our principal source of cash provided by operating activities. A diversified retail customer mix, primarily consisting of rate-regulated residential, commercial, and industrial customers, provides us with a reasonably predictable source of cash. In addition to using cash provided by operating activities, we use available cash, drawings under committed credit agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings to support normal operations and temporary capital requirements. We may reduce our short-term borrowings with cash provided by operations or, at our discretion, with long-term borrowings, or, in the case of Ameren Missouri and Ameren Illinois, with capital contributions from Ameren (parent). As of ~~March 31,~~June 30, 2023, there have been no material changes other than in the ordinary course of business related to cash requirements arising from these long-term commitments provided in Item 7 of the Form 10-K.

We expect to make significant capital expenditures over the next five years, supported by a combination of long-term debt and equity, as we invest in our electric and natural gas utility infrastructure to support overall system reliability, grid modernization, renewable energy target requirements, environmental compliance, and other improvements. For additional information about our long-term debt outstanding, including maturities due within one year, and the applicable interest rates, see Note 5 – Long-term Debt and Equity Financings under Part II, Item 8 of the Form 10-K and Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report. As part of its funding plan for capital expenditures, Ameren is using newly issued shares of common stock ~~rather than market-purchased shares,~~ to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 2027. Ameren expects these equity issuances to total about $100 million annually. In addition, Ameren has an ATM program under which Ameren may offer and sell from time to time common stock, which includes the ability to enter into forward sales agreements, subject to market conditions and other factors. There were no shares issued under the ATM program for the three and six months ended ~~March 31,~~June 30, 2023. As of ~~April~~June 30, 2023, Ameren has entered into multiple forward sale agreements under the ATM program with various counterparties relating to ~~3.8~~4.3 million shares of common stock. Ameren expects to settle approximately $300 million

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of the forward sale agreements with physical delivery of 3.2 million shares of common stock by December 31, 2023. Also, Ameren plans to issue approximately $500 million of equity each year from 2024 to 2027, in addition to issuances under the DRPlus and employee benefit plans. As of ~~March 31,~~June 30, 2023, Ameren had approximately ~~$980~~$910 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of ~~March 31,~~June 30, 2023. Ameren expects its equity to total capitalization to be about 45% ~~through~~by December 31, 2027, with the long-term intent to support solid investment-grade credit ratings. See Long-term Debt and Equity below and Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for additional information on the ATM program, including the forward sale agreements under the ATM ~~program relating to common stock.~~program.

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 ~~March 31,~~June 30, 2023, for Ameren, Ameren Missouri, and Ameren Illinois. With the credit capacity available under the Credit Agreements, and cash and cash equivalents, Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, had net available liquidity of ~~$1.4~~$1.3 billion at ~~March 31,~~June 30, 2023. Additionally, as of ~~March 31,~~June 30, 2023, Ameren could have settled the forward sale agreements with physical delivery of ~~3.4~~4.3 million shares of common stock to the respective counterparties in exchange for cash of ~~$317~~$389 million. See Credit Facility Borrowings and Liquidity and Long-term Debt and Equity below for additional information.

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The following table presents net cash provided by (used in) operating, investing, and financing activities for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022:


		Net Cash Provided By Operating Activities								Net Cash Used In Investing Activities						Net Cash Provided By Financing Activities							Net Cash Provided By Operating Activities								Net Cash Used In Investing Activities						Net Cash Provided By Financing Activities
		2023			2022			Variance		2023		2022		Variance		2023		2022		Variance			2023			2022			Variance		2023		2022		Variance		2023		2022		Variance
Ameren	Ameren	$	496	(a)	$	388	(a)	$	108	$	(964)	$	(780)	$	(184)	$	489	$	391	$	98	Ameren	$	1,111	(a)	$	872	(a)	$	239	$	(1,889)	$	(1,552)	$	(337)	$	808	$	686	$	122

Ameren Missouri	Ameren Missouri	153			56			97		(513)		(417)		(96)		358		362		(4)		Ameren Missouri	443			181			262		(980)		(818)		(162)		532		636		(104)
Ameren Illinois	Ameren Illinois	373		(a)	342		(a)	31		(407)		(342)		(65)		60		4		56		Ameren Illinois	637		(a)	675		(a)	(38)		(846)		(699)		(147)		247		37		210

(a)Both Ameren and Ameren Illinois’ cash provided by operating activities included cash outflows of ~~$25~~$56 million and ~~$16~~$37 million for the FEJA electric energy-efficiency rider and $2$5 million and $3 million for the customer generation rebate program for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022, respectively.

Cash Flows from Operating Activities

Our cash provided by operating activities is affected by fluctuations of trade accounts receivable, inventories, and accounts and wages payable, among other things, as well as the unique regulatory environment for each of our businesses. Substantially all expenditures related to fuel, purchased power, and natural gas purchased for resale are recovered from customers through rate adjustment mechanisms, which may be adjusted without a traditional regulatory rate review, subject to prudence reviews. Similar regulatory mechanisms exist for certain other operating expenses that can also affect the timing of cash provided by operating activities. The timing of cash payments for costs recoverable under our regulatory mechanisms differs from the recovery period of those costs. Additionally, the seasonality of our electric and natural gas businesses, primarily caused by seasonal customer rates and changes in customer demand due to weather, significantly affects the amount and timing of our cash provided by operating activities.

As a result of the significant increase in customer demand and prices for natural gas and electricity experienced in mid-February 2021 due to extremely cold weather, Ameren Missouri and Ameren Illinois had under-recovered costs for the month of February 2021 under their PGA clauses and, for Ameren Missouri, under the FAC (Ameren Missouri – PGA $53 million, FAC $50 million; Ameren Illinois – PGA $221 million). Ameren Missouri’s PGA under-recovery is being collected from customers over 36 months beginning November 2021, pursuant to an October 2021 MoPSC order, and the FAC under-recovery was collected over eight months beginning October 2021. Ameren Illinois collected the PGA under-recovery over 18 months beginning April 2021.

Ameren

Ameren’s cash provided by operating activities increased ~~$108~~$239 million in the first ~~three~~six months of 2023, compared with the year-ago period. The following items contributed to the increase:

•A ~~$143~~$237 million decrease in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.

•A ~~$10 million decrease in the cost of natural gas held in storage, primarily at Ameren Illinois, because of lower prices.~~

•~~An $8~~$158 million increase resulting from increased customer collections, primarily from base rate increases effective February 28, 2022, pursuant to Ameren Missouri’s December 2021 electric rate order, electric transmission rate base growth, and an increase attributable to other regulatory mechanisms, partially offset by a decrease under Ameren Illinois’ PGA resulting from the recovery in 2022 of costs for the mid-February 2021 weather event discussed ~~above~~above.

•A $45 million decrease in the cost of natural gas held in storage, primarily at Ameren Illinois, because of lower commodity prices.

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•A $40 million decrease in payments for nuclear refueling and ~~a decrease attributable~~maintenance outages at Ameren Missouri’s Callaway Energy Center, primarily due to ~~other regulatory mechanisms.~~the spring 2022 outage. Ameren Missouri’s next refueling and maintenance outage at its Callaway Energy Center is scheduled for the fall of 2023.

The following items partially offset the increase in Ameren’s cash from operating activities between periods:

•A ~~$33~~$58 million decrease due to the timing of payments for accounts payable and prepaid expenses.

•A $54 million increase in coal inventory levels at Ameren Missouri, primarily due to fewer transportation delays and less coal burned in 2023 as a result of ~~lower off-system sales~~decreased generation volumes driven by lower market power prices and decreased retail load because of both milder summer temperatures and warmer winter temperatures.

•~~An $11~~A $40 million increase in interest payments, primarily due to an increase in the average outstanding debt and an increase in interest rates.

•A $23 million increase in purchases of materials and supplies inventories to support operations as levels were increased to mitigate against potential supply disruptions.

•~~An $11~~A $12 million ~~increase~~decrease resulting from income tax payments of $5 million in ~~interest payments,~~2023, compared with income tax refunds of $7 million in 2022, primarily due to ~~an increase in~~increased income tax extension payments, which are based on the ~~average outstanding debt~~preceding year’s taxable income and ~~an increase in interest rates.~~estimated payments.

•A $9 million increase in property tax payments at Ameren Missouri, primarily due to higher assessed property tax values.

Ameren Missouri

Ameren Missouri’s cash provided by operating activities increased ~~$97~~$262 million in the first ~~three~~six months of 2023, compared with the year-ago period. The following items contributed to the increase:

•A ~~$112~~$199 million decrease in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.

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•A ~~$35~~$142 million increase resulting from increased customer collections, primarily from base rate increases effective February 28, 2022, pursuant to the December 2021 electric rate order ~~partially offset by a decrease~~and an increase attributable to other regulatory mechanisms.

•A $40 million decrease in payments for nuclear refueling and maintenance outages at the Callaway Energy Center, primarily due to the spring 2022 outage. The next refueling and maintenance outage at the Callaway Energy Center is scheduled for the fall of 2023.

The following items partially offset the increase in Ameren Missouri’s cash from operating activities between periods:

•A ~~$33~~$54 million increase in coal inventory levels, primarily due to fewer transportation delays and less coal burned in 2023 as a result of ~~lower off-system sales~~decreased generation volumes driven by lower market power prices and decreased retail load because of both milder summer temperatures and warmer winter temperatures.

•A ~~$12~~$16 million increase in purchases of materials and supplies inventories to support operations as levels were increased to mitigate against potential supply disruptions.

•A $9 million increase in property tax payments, primarily due to higher assessed property tax values.

•A $7 million decrease due to the timing of payments for accounts payable and prepaid expenses.

Ameren Illinois

Ameren Illinois’ cash provided by operating activities ~~increased $31~~decreased $38 million in the first ~~three~~six months of 2023, compared with the year-ago period. The following items contributed to the ~~increase:~~decrease:

•A $95 million decrease resulting from income tax payments to Ameren (parent) of $64 million in 2023, compared with income tax refunds from Ameren (parent) of $31 million in 2022, pursuant to the tax allocation agreement, primarily due to increased income tax extension payments, which are based on the preceding year’s taxable income and estimated payments.

•A $33 million decrease due to the timing of payments for accounts payable and prepaid expenses.

•A $17 million increase in interest payments, primarily due to an increase in the average outstanding debt and an increase in interest rates.

The following items partially offset the decrease in Ameren Illinois’ cash from operating activities between periods:

•A $42 million decrease in the cost of natural gas held in storage because of lower commodity prices.

•A $38 million decrease in net collateral posted with counterparties, primarily due to changes in the market prices of power and natural gas.

•~~A $10~~An $16 million ~~decrease in the cost of natural gas held in storage because of lower prices.~~

~~The~~ increase ~~in Ameren Illinois’ cash~~resulting from ~~operating activities between periods was~~increased customer collections, primarily from electric transmission rate base growth and an increase attributable to other regulatory mechanisms, partially offset by ~~a $22 million decrease in customer collections, primarily because of~~ a decrease under the PGA resulting from the recovery in 2022 of

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costs for the mid-February 2021 weather event discussed ~~above, partially offset by a net increase attributable to other regulatory recovery mechanisms.~~above.

Cash Flows from Investing Activities

Ameren’s cash used in investing activities increased ~~$184~~$337 million during the first ~~three~~six months of 2023, compared with the year-ago period, primarily as a result of a ~~$157~~$284 million increase in capital expenditures, largely resulting from increased expenditures for electric transmission upgrades at Ameren Missouri, Ameren Illinois, and ATXI and electric distribution infrastructure upgrades at Ameren Missouri and Ameren Illinois. ATXI’s capital expenditures increased $25 million during the first six months of 2023, compared with the year-ago period. In addition, in 2022, Ameren Missouri received $17 million in insurance proceeds for the Callaway Energy Center’s generator.

Ameren Missouri’s cash used in investing activities increased ~~$96~~$162 million during the first ~~three~~six months of 2023, compared with the year-ago period, primarily as a result of a ~~$67~~$108 million increase in capital expenditures, largely resulting from increased expenditures for electric transmission and distribution infrastructure upgrades. In addition, in 2022, Ameren Missouri received $17 million in insurance proceeds for the Callaway Energy Center’s generator.

Ameren Illinois’ cash used in investing activities increased ~~$65~~$147 million during the first ~~three~~six months of 2023, compared with the year-ago period, as a result of a ~~$65~~$145 million increase in capital expenditures, largely resulting from increased expenditures for electric transmission and distribution infrastructure upgrades.

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 consolidated financing activities increased ~~$98~~$122 million during the first ~~three~~six months of 2023, compared with the year-ago period. During the first ~~three~~six months of 2023, Ameren utilized proceeds from the issuance of long-term debt of ~~$499~~$997 million for capital expenditures, ~~and~~ to repay then-outstanding short-term ~~debt.~~debt, and to repay $100 million of long-term debt maturities. In addition, during the first ~~three~~six months of 2023, Ameren utilized proceeds from net commercial paper issuances of ~~$179~~$260 million along with cash provided by operating activities to fund, in part, capital expenditures. In comparison, during the first ~~three~~six months of 2022, Ameren utilized proceeds of $524 million of long-term debt to repay then-outstanding short-term debt and for capital expenditures. In addition, during the first six months of 2022, Ameren utilized proceeds from net commercial paper issuances of ~~$555~~$475 million ~~along with~~and cash provided by operating activities to fund, in part, capital expenditures. During the first ~~three~~six months of 2023, Ameren paid common stock dividends of ~~$165~~$330 million, compared with ~~$152~~$305 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 ~~was comparable between periods.~~decreased $104 million during the first six months of 2023, compared with the year-ago period. During the first ~~three~~six months of 2023, Ameren Missouri utilized proceeds from the issuance of long-term debt of $499 million for capital expenditures and to repay then-outstanding short-term debt. During the first ~~three~~six months of 2023, Ameren Missouri ~~repaid net commercial paper borrowings totaling $132 million. In comparison, during the first three months of 2022, Ameren Missouri~~ utilized ~~net~~ proceeds from net commercial paper issuances of ~~$363~~$44 million and cash provided by operating activities to fund, in part, capital expenditures. In comparison, during the first six months of 2022, Ameren Missouri utilized proceeds from the issuance of $524 million to repay then-outstanding short-term debt and for capital expenditures. In addition, during the first six months of 2022, Ameren Missouri utilized proceeds from net commercial paper issuances of $120 million and cash provided by operating activities to fund, in part, capital expenditures.

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Ameren Illinois’ cash provided by financing activities increased ~~$56~~$210 million during the first ~~three~~six months of 2023, compared with the year-ago period. During the first ~~three~~six months of 2023, Ameren Illinois utilized proceeds from the issuance of long-term debt of $498 million to repay then-outstanding short-term debt and $100 million of long-term debt maturities. In addition, during the first six months of 2023, Ameren Illinois repaid net commercial paper borrowings totaling $147 million. In comparison, during the first six months of 2022, Ameren Illinois utilized proceeds from net commercial paper issuances of ~~$60~~$38 million and cash provided by operating activities to fund, in part, capital ~~expenditures, compared to $4 million in such proceeds in the year-ago period.~~expenditures.

See Long-term Debt and Equity in this section for additional information on issuances of long-term debt, issuances of common stock, and noncash settlement of a financing obligation.

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Credit Facility Borrowings and Liquidity

The following table presents Ameren’s consolidated liquidity as of ~~March 31,~~June 30, 2023:

Available at ~~March 31,~~June 30, 2023

Ameren (parent) and Ameren Missouri:

Missouri Credit Agreement – borrowing capacity

1,400

Less: Ameren (parent) commercial paper outstanding

~~428~~494

Less: Ameren Missouri commercial paper outstanding

~~197~~373

Less: Ameren Missouri letters of credit

Missouri Credit Agreement – subtotal

~~774~~532

Ameren (parent) and Ameren Illinois:

Illinois Credit Agreement – borrowing capacity

1,200

Less: Ameren (parent) commercial paper outstanding

~~299~~345

Less: Ameren Illinois commercial paper outstanding

~~324~~117

Illinois Credit Agreement – subtotal

~~577~~738

Subtotal

~~1,351~~1,270

Add: Cash and cash equivalents

107

Net Available Liquidity(a)

~~1,361~~1,277

(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 $2.6 billion of credit until maturity in December 2027. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on the Credit Agreements. During the ~~three~~six months ended ~~March 31,~~June 30, 2023, Ameren (parent), Ameren Missouri, and Ameren Illinois each issued commercial paper. Borrowings under the Credit Agreements and commercial paper issuances are based upon available interest rates at the time of the borrowing or issuance.

Ameren has a money pool agreement with and among its utility subsidiaries to coordinate and to provide for certain short-term cash and working capital requirements. As short-term capital needs arise, and based on availability of funding sources, Ameren Missouri and Ameren Illinois will access funds from the utility money pool, the Credit Agreements, or the commercial paper programs depending on which option has the lowest interest rates.

See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information on credit agreements, commercial paper issuances, Ameren’s money pool arrangements and related borrowings, and relevant interest rates.

The issuance of short-term debt securities by Ameren’s utility subsidiaries is subject to FERC approval under the Federal Power Act. In January 2023, the FERC issued orders authorizing Ameren Missouri, Ameren Illinois, and ATXI to issue up to $1 billion, $1 billion, and $300 million, respectively, of short-term debt securities through January 2025.

The Ameren Companies continually evaluate the adequacy and appropriateness of their liquidity arrangements for changing business conditions. When business conditions warrant, changes may be made to existing credit agreements or to other borrowing arrangements, or other arrangements may be made.

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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 maturities of long-term debt for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022:


		Month Issued, Redeemed, or Matured	2023			2022			Month Issued, Redeemed, or Matured	2023			2022
Issuances of Long-term Debt	Issuances of Long-term Debt							Issuances of Long-term Debt

Ameren Missouri:	Ameren Missouri:							Ameren Missouri:
5.45% First mortgage bonds due 2053	5.45% First mortgage bonds due 2053	March	499			—		5.45% First mortgage bonds due 2053	March	499			—

3.90% First mortgage bonds due 2052(a)								3.90% First mortgage bonds due 2052(a)	April	—			524
Ameren Illinois:								Ameren Illinois:
4.95% First mortgage bonds due 2033								4.95% First mortgage bonds due 2033	May	498			—

Total Ameren long-term debt issuances	Total Ameren long-term debt issuances		$	499		$	—	Total Ameren long-term debt issuances		$	997		$	524
Issuances of Common Stock	Issuances of Common Stock							Issuances of Common Stock
Ameren:	Ameren:							Ameren:
DRPlus and 401(k)~~(b)~~(c)	DRPlus and 401(k)~~(b)~~(c)	Various	$	5		$	5	DRPlus and 401(k)~~(b)~~(c)	Various	$	16		$	17

Total Ameren common stock issuances~~(c)~~(d)	Total Ameren common stock issuances~~(c)~~(d)		$	5		$	5	Total Ameren common stock issuances~~(c)~~(d)		$	16		$	17

Maturities of Long-term Debt	Maturities of Long-term Debt							Maturities of Long-term Debt
Ameren Missouri:	Ameren Missouri:							Ameren Missouri:
Audrain County agreement (Audrain County CT) due 2023	Audrain County agreement (Audrain County CT) due 2023	January	$	240	(d)	$	—	Audrain County agreement (Audrain County CT) due 2023	January	$	240	(e)	$	—

Ameren Illinois:								Ameren Illinois:
0.375% First mortgage bonds due 2023								0.375% First mortgage bonds due 2023	June	100
Total Ameren long-term debt maturities	Total Ameren long-term debt maturities		$	240		$	—	Total Ameren long-term debt maturities		$	340		$	—

(a)Ameren Missouri intends to allocate an amount equal to the net proceeds to sustainability projects meeting certain eligible criteria.

(b)Ameren issued a total of ~~0.1~~0.2 million and ~~0.1~~0.3 million shares of common stock under its DRPlus and 401(k) plan infor the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022, respectively.

~~(b)~~(c)Excludes a $7 million and $8 million receivable at ~~March 31,~~June 30, 2023 and 2022, respectively.

~~(c)~~(d)Excludes 0.5 million and 0.4 million shares of common stock valued at $37 million and $31 million issued for no cash consideration in connection with stock-based compensation for the ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022, respectively.

~~(d)~~(e)In January 2023, Ameren Missouri and Audrain County mutually agreed to terminate a financing obligation agreement related to the CT energy center in Audrain County, which was scheduled to expire in December 2023. No cash was exchanged in connection with the termination of the agreement as the $240 million principal amount of the financing obligation due from Ameren Missouri was equal to the amount of bond service payments due to Ameren Missouri.

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, including Ameren Missouri’s March 2023 issuance of first mortgage bonds, the use of those proceeds, Ameren’s forward equity sale agreements, and the ATM program.

Indebtedness Provisions and Other Covenants

At ~~March 31,~~June 30, 2023, the Ameren Companies were in compliance with the provisions and covenants contained in their credit agreements, indentures, and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreements. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for a discussion of provisions, applicable cross-default provisions, and covenants contained in our credit agreements, in ATXI’s note purchase agreements, and in certain of the Ameren Companies’ indentures and articles of incorporation.

We consider access to short-term and long-term capital and credit markets to be a significant source of funding for capital requirements not satisfied by cash provided by our operating activities. Inability to raise capital on reasonable terms, particularly during times of uncertainty in the capital and credit markets, could negatively affect our ability to maintain and expand our businesses. After assessing their respective current operating performance, liquidity, and credit ratings (see Credit Ratings below), Ameren, Ameren Missouri, and Ameren Illinois each believes that it will continue to have access to the capital and credit markets on reasonable terms. However, events beyond Ameren’s, Ameren Missouri’s, 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

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requirements, historical earnings and cash flow, projected earnings, impacts of regulatory orders or legislation, and other key business considerations. Ameren expects its dividend payout ratio to be between 55% and 70% 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 ~~March 31,~~June 30, 2023, none of these

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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 ~~three~~six months ended ~~March 31,~~June 30, 2023 and 2022:


		Three Months					Six Months
		2023		2022			2023		2022
Ameren	Ameren	$	165	$	152	Ameren	$	330	$	305

ATXI	ATXI	55		—		ATXI	75		—

Credit Ratings

Our credit ratings affect our liquidity, our access to the capital and credit markets, our cost of borrowing under our credit facilities and our commercial paper programs, and our collateral posting requirements under commodity contracts.

The following table presents the principal credit ratings by Moody’s and S&P, as applicable, effective on the date of this report:

Moody’s

S&P

Ameren:

Issuer/corporate credit rating

Baa1

BBB+

Senior unsecured debt

Baa1

BBB

Commercial paper

P-2

A-2

Ameren Missouri:

Issuer/corporate credit rating

Baa1

BBB+

Secured debt

Senior unsecured debt

Baa1

Not Rated

Commercial paper

P-2

A-2

Ameren Illinois:

Issuer/corporate credit rating

BBB+

Secured debt

Senior unsecured debt

BBB+

Commercial paper

P-2

A-2

ATXI:

Issuer credit rating

Not Rated

Senior unsecured debt

Not Rated

A credit rating is not a recommendation to buy, sell, or hold securities. It should be evaluated independently of any other rating. Ratings are subject to revision or withdrawal at any time by the rating organization.

Collateral Postings

Any weakening of our credit ratings may reduce access to capital and trigger additional collateral postings and prepayments. Such changes may also increase the cost of borrowing, resulting in an adverse effect on earnings. Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts were immaterial and cash collateral posted by external parties were ~~immaterial~~$46 million for Ameren and Ameren Illinois at ~~March 31,~~June 30, 2023. A sub-investment-grade issuer or senior unsecured debt rating (below “Baa3” from Moody’s or below “BBB-” from S&P) at ~~March 31,~~June 30, 2023, 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 ~~$122~~$587 million, ~~$59~~$526 million, and ~~$63~~$61 million, respectively.

Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at ~~March 31,~~June 30, 2023, if market prices were 15% higher or lower than ~~March 31,~~June 30, 2023 levels in the next 12 months and 20% higher or lower thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, and Ameren Illinois could be required to post an immaterial amount, compared to each company’s liquidity, of collateral or provide other assurances for certain trade and contractual obligations.

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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 2023 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

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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

•We are observing inflationary pressures on the prices of certain commodities, labor, services, materials, and supplies, as well as increasing interest rates. Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel, purchased power, and natural gas supply. Additionally, for certain non-commodity cost changes, the use of trackers, riders, ~~and~~ formula ratemaking, and future test years, as applicable, mitigates our exposure. The inflationary pressures and increasing interest rates could impact our ability to control costs and/or make substantial investments in our businesses, including our ability to recover costs and investments, and to earn our allowed ROEs within frameworks established by our regulators, while maintaining rates that are affordable to our customers. In addition, these inflationary pressures and increasing interest rates could adversely affect our customers’ usage of, or payment for, our services. In April 2022, the MISO released the results of its 2022 capacity auction, which projected a capacity shortage in the central region of the MISO footprint, which includes Ameren Missouri’s and Ameren Illinois’ service territories. The annual auction resulted in a capacity price increase from $5 per MW-day for June 2021 through May 2022 to $237 per MW-day for June 2022 through May 2023. Ameren Illinois’ purchased power costs increased by nearly $500 million for calendar year 2022, compared to 2021, largely due to higher energy and capacity prices. Higher purchased power costs for calendar year 2023, compared to 2021, are also likely but Ameren Illinois cannot reasonably estimate the amount of the increase as capacity pricing for June 2023 through December 2023 will be determined once the results of the 2023 MISO capacity auction are announced in mid-May 2023. Because of the power procurement riders, the difference between actual purchased power costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. These pass-through costs do not affect Ameren Illinois’ net income, as any change in costs are offset by a corresponding change in revenues. Also, largely due to the capacity price set by the April 2022 MISO auction, Ameren Missouri’s capacity revenues and purchased power costs increased by approximately $370 million and $360 million, respectively, for the calendar year 2022, compared to 2021. Ameren Missouri sells nearly all of its capacity to the MISO and purchases the capacity it needs to supply its native load sales from the MISO. Higher capacity revenues and purchased power costs for calendar year 2023, compared to 2021, are also likely but Ameren Missouri cannot reasonably estimate the amount of the increases as capacity pricing for June 2023 through December 2023 will be determined once the results of the 2023 MISO capacity auction are announced in mid-May 2023. Capacity revenues and purchased power costs are a 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.

•The PISA permits Ameren Missouri to defer and recover 85% of the depreciation expense for investments in qualifying property, plant, and equipment placed in service and not included in base rates. Investments not eligible for recovery under the PISA include amounts related to new nuclear and natural gas generating units and service to new customer premises. Additionally, the PISA permits Ameren Missouri to earn a return at the applicable WACC on rate base that incorporates those qualifying investments, as well as changes in total accumulated depreciation excluding retirements and plant-related deferred income taxes since the previous regulatory rate review. The regulatory asset for accumulated PISA deferrals also earns a return at the applicable WACC until added to rate base prospectively. Ameren Missouri recognizes an offset to interest charges for its cost of debt relating to each return allowed under the PISA, with the difference between the applicable WACC and its cost of debt recognized in revenues when recovery of PISA deferrals is reflected in customer rates. Approved PISA deferrals are recovered over a period of 20 years following a regulatory rate review. Additionally, under the RESRAM, Ameren Missouri is permitted to recover the 15% of depreciation expense not recovered under the PISA, and earn a return at the applicable WACC for investments in renewable generation plant placed in service to comply with Missouri’s renewable energy standard. Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. The PISA and the RESRAM mitigate the effects of regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under the PISA and the remaining 15% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. As a result of the PISA election, additional provisions of the law apply to Ameren Missouri, including limitations on electric customer rate increases. The current rate limitation, which is effective through 2023, is a 2.85% cap on the compound annual growth rate in the average overall customer rate per kilowatthour, based on the electric rates that became effective in April 2017, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 2018 MoPSC order. The rate increase ~~proposed in~~approved by the ~~April~~June 2023 ~~nonunanimous stipulation and agreement filed in Ameren Missouri's 2022~~MoPSC electric ~~service regulatory~~ rate ~~review does~~order did not exceed ~~this~~the rate increase ~~limitation.~~limitation applicable through 2023. Missouri Senate Bill 745 became effective on August 28, 2022. The law extended Ameren Missouri’s PISA election through December 2028 and allows for an additional extension through December 2033 if requested by Ameren Missouri and approved by the MoPSC, among other things. The law also established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1, 2024, and will be based on the revenue requirement established in the immediately preceding rate order.

•In June 2023, the MoPSC issued an order that resulted in an increase of $140 million to Ameren Missouri’s annual revenue requirement for electric retail service. The order increased the annualized base level of net energy costs pursuant to the FAC by approximately $40 million from the base level established in the MoPSC’s December 2021 electric rate order. The order also changed annualized depreciation, regulatory asset and liability amortization amounts, and the base level of expenses for trackers. On an annualized basis, these changes reflect approximate increases in “Depreciation and amortization” of $90 million and “Other income, net”, of $100 million, related to non-service pension and postretirement benefit income, on Ameren’s and Ameren Missouri’s consolidated statements of income. The new rates became effective on July 9, 2023. As a result of this order, Ameren Missouri expects a year-over-year increase to 2023 earnings, compared to 2022, of approximately $44 million ($11 million in the second quarter, $23 million in the third quarter, and $10 million in the fourth quarter).

•In 2018, the MoPSC issued an order approving Ameren Missouri’s MEEIA 2019 plan. The plan includes a portfolio of customer energy-efficiency and demand response programs through December 2023. Ameren Missouri intends to invest approximately $350 million over the life of the plan, including $75 million in 2023. The plan includes the continued use of the MEEIA rider, which allows Ameren Missouri

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to collect from, or refund to, customers any difference in actual MEEIA program costs and related lost electric margins and the amounts collected from customers. In addition, the plan includes a performance incentive that provides Ameren Missouri an opportunity to earn additional revenues by achieving certain customer energy-efficiency goals. If the target spending goals are achieved for 2023, the performance incentive would result in revenues of $12 million in 2023.

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•In ~~March~~August 2023, Ameren Missouri, the MoPSC staff, and the MoOPC filed a ~~proposed customer energy-efficiency plan~~nonunanimous stipulation and agreement with the MoPSC ~~under~~to extend Ameren Missouri’s MEEIA 2019 program through 2024. The stipulation and agreement, which is subject to MoPSC approval, includes the ~~MEEIA. This filing proposed a three-year plan, which includes~~establishment of a portfolio of customer energy-efficiency programs ~~along with the continued use of the MEEIA rider discussed above.~~for 2024 and performance incentives that would provide Ameren Missouri an opportunity to earn revenues, including $12 million if Ameren Missouri achieves certain energy-efficiency goals in 2024. If ~~the plan is~~ approved, Ameren Missouri ~~intends~~expects to invest ~~$122~~$76 million ~~annually~~ in ~~the proposed customer~~ energy-efficiency programs from 2024 to 2026. In addition, Ameren Missouri requested performance incentives applicable to each plan year to earn additional revenues by achieving certain customer energy-efficiency and target spending goals. If 100% of the goals are achieved, Ameren Missouri would earn additional revenues totaling $55 million over the three-year plan. Ameren Missouri also requested additional performance incentives applicable to each plan year totaling up to $14 million over the three-year plan, if Ameren Missouri exceeds 100% of the goals.in 2024. The MoPSC is under no deadline to issue an order in this proceeding.

•In August 2022, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by $316 million. In April 2023, Ameren Missouri, the MoPSC staff, the MoOPC, and certain intervenors filed a nonunanimous stipulation and agreement with the MoPSC to increase Ameren Missouri’s annual revenues for electric service by $140 million. The remaining intervenors did not object to the agreement. A decision by the MoPSC on the nonunanimous stipulation and agreement is expected by June 2023, with new rates expected to take effect on July 1, 2023. Ameren Missouri cannot predict whether the MoPSC will approve the stipulation and agreement, or, if approved, whether any application for rehearing or appeal will be filed, or the outcome if so filed. In addition, if the MoPSC does not approve the stipulation and agreement, Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient for Ameren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.

•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 10.52% ROE, which includes a ~~50 basis point~~50-basis-point incentive adder for participation in an RTO, the revenue requirements included in 2023 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are $476 million and $194 million, respectively. These revenue requirements represent an increase in Ameren Illinois’ revenue requirement of $54 million and a decrease in ATXI’s revenue requirement of $1 million from the revenue requirements reflected in 2022 rates, primarily due to higher expected rate base at Ameren Illinois and a lower expected rate base at ATXI. These rates will affect Ameren Illinois’ and ATXI’s cash receipts during 2023, but will not determine their respective electric transmission service operating revenues, which will instead be based on 2023 actual recoverable costs, rate base, and a return on rate base at the applicable WACC as calculated under the FERC formula ratemaking framework.

•The allowed base ROE for FERC-regulated transmission rates previously charged under the MISO tariff is the subject of pending proceedings. Depending on the outcome of the proceedings, the transmission rates charged during previous periods and the currently effective rates may be subject to change and refund. In March 2020, the FERC issued a Notice of Proposed Rulemaking on its transmission incentives policy, which increased the incentive ROE for participation in an RTO to 100 basis points from the current 50 basis points and revised the parameters for awarding incentives, while limiting the overall incentives to a cap of 250 basis points, among other things. In April 2021, the FERC issued a Supplemental Notice of Proposed Rulemaking, which proposes 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, or any further order on base ROE. A ~~50 basis point~~50-basis-point change in the FERC-allowed ROE would affect Ameren’s and Ameren Illinois’ annual net income by an estimated $14 million and $10 million, respectively, based on each company’s 2023 projected rate base.

•Ameren Illinois’ electric distribution service performance-based formula ratemaking framework under the IEIMA allows Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis to reflect actual recoverable costs incurred and a return at the applicable WACC on year-end rate base through 2023. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the year. Pursuant to December 2022 and March 2021 ICC orders, Ameren Illinois used the current IEIMA formula framework to establish annual customer rates effective through 2023, and ~~expects to~~will reconcile the related revenue requirement for customer rates established for 2023. As such, Ameren Illinois’ 2023 revenues will reflect actual recoverable costs, year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. By law, the decoupling provisions extend beyond the end of existing performance-based formula ratemaking, which ensures that Ameren Illinois’ electric distribution revenues authorized

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in a regulatory rate review are not affected by changes in sales volumes. In April 2023, Ameren Illinois filed for a reconciliation adjustment to its 2022 electric distribution service revenue requirement with the ~~ICC,~~ICC. In July 2023, Ameren Illinois filed a revised reconciliation adjustment, requesting recovery of ~~$127~~$125 million. An ICC decision in this proceeding is required by December 2023, and any approved adjustment would be collected from customers in 2024.

•Pursuant to the IETL, which was enacted in September 2021, Ameren Illinois may file an MYRP with the ICC to establish base rates for electric distribution service to be charged to customers for each calendar year of a four-year period. The base rates for a particular calendar year are based on forecasted recoverable costs and an ICC-determined ROE applied to Ameren Illinois’ forecasted average annual rate base using a forecasted capital structure, with a common equity ratio of up to 50% being deemed prudent and reasonable by law and a higher equity ratio requiring specific ICC approval. The ROE determined by the ICC for each calendar year of the four-year period is subject to annual adjustments based on certain performance incentives and penalties. An MYRP allows Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis, subject to a reconciliation cap and adjustments to the ROE. If a given year’s revenue amount collected from customers varies from the approved revenue requirement, an adjustment would be made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance would then be collected from, or refunded to, customers within two years from the end of the applicable annual period. Ameren Illinois’ existing riders will remain effective under the ~~January 2023~~ MYRP discussed below, and will continue to remain effective beyond 2027 whether it elects to file an MYRP or a traditional regulatory rate review. Additionally, electric distribution service revenues continue to be decoupled from sales volumes under either election.

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•In January 2023, Ameren Illinois filed an MYRP with the ~~ICC~~ICC. In July 2023, Ameren Illinois filed a revised MYRP requesting approval of forecasted revenue requirements for electric distribution service for 2024, 2025, 2026, and 2027 of ~~$1,282~~$1,291 million, ~~$1,373~~$1,387 million, ~~$1,477~~$1,484 million, and ~~$1,556~~$1,560 million, respectively. Pursuant to a provision under the IETL that permits initial rate increases under an MYRP to be phased in, Ameren Illinois’ filing proposes to defer 50% of the requested 2024 rate increase of ~~$171~~$179 million as a regulatory asset to be collected from customers in 2026. That regulatory asset would earn a return at the applicable WACC. An ICC decision in this proceeding is required by December 2023, with new rates effective starting in January 2024. Ameren Illinois cannot predict the level of any electric distribution service rate change the ICC may approve, or whether any rate change that may eventually be approved will be sufficient for Ameren Illinois to recover its costs to the extent those costs are subject to and exceed the MYRP reconciliation cap and earn a reasonable return on its investments when the rate change goes into effect. If the rates approved by the ICC are materially different from its forecasted spend, Ameren Illinois may adjust its overall spending, both operating and capital.

•In December 2022, the ICC issued an order in Ameren Illinois’ annual update filing that approved a $61 million increase in Ameren Illinois’ electric distribution service rates beginning in January 2023. Ameren Illinois’ 2023 electric distribution service revenues will be based on its 2023 actual recoverable costs, 2023 year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. As of ~~March 31,~~June 30, 2023, Ameren Illinois expects its 2023 electric distribution year-end rate base to be $4.2 billion. The 2023 revenue requirement reconciliation adjustment will be collected from, or refunded to, customers in 2025. A ~~50 basis point~~50-basis-point change in the annual average of the monthly yields of the 30-year United States Treasury bonds would result in an estimated $12 million change in Ameren’s and Ameren Illinois’ annual net income, based on Ameren Illinois’ 2023 projected year-end rate base, including electric energy-efficiency investments. Ameren Illinois’ recognized ROE for the first ~~three months~~half of 2023 was based on an annual average of the monthly yields of the 30-year United States Treasury bonds of ~~3.81%~~3.84%.

•In January 2023, Ameren Illinois filed a request with the ICC seeking approval to increase its annual revenues for natural gas delivery ~~service~~service. In July 2023, Ameren Illinois filed a revised request seeking to increase its annual revenues by ~~$160~~$148 million, which ~~included~~includes an estimated $77 million of annual revenues that would otherwise be recovered under the QIP and other riders. In an attempt to reduce regulatory lag, Ameren Illinois used a 2024 future test year in this proceeding. A decision by the ICC in this proceeding is required by late November 2023, with new rates expected to be effective in early December 2023. Ameren Illinois cannot predict the level of any delivery service rate change the ICC may approve, nor whether any rate change that may eventually be approved will be sufficient to enable Ameren Illinois to recover its costs and to earn a reasonable return on investments when the rate changes go into effect. Without legislative action, the QIP will expire after December 2023.

•Pursuant to Illinois law, Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The allowed ROE on electric energy-efficiency investments can be increased or decreased by up to 200 basis points, depending on the achievement of annual energy savings goals. While the ICC has approved a plan for Ameren Illinois to invest approximately $120 million per year in electric energy-efficiency programs through 2025, the ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs. The electric energy-efficiency program investments and the return on those investments are collected from customers through a rider and are not recovered through the electric distribution service performance-based formula ratemaking framework.

•In May 2023, the MISO released the results of its April 2023 capacity auction, which included capacity price decreases in the central region of the MISO footprint, where Ameren Missouri’s and Ameren Illinois’ service territories are located. Capacity prices decreased from $237 per MW-day for June 2022 through May 2023 pursuant to the April 2022 capacity auction to seasonal prices ranging from $2 to $15 per MW-day for June 2023 through May 2024. Based on estimated power prices and customer demand as of June 30, 2023, the capacity prices set by the April 2023 MISO auction, and the amounts of energy and capacity hedged through IPA procurement events, Ameren Illinois estimates a decrease to purchased power costs for calendar year 2023, compared to 2022, of approximately $100 million. The actual decrease to purchased power costs will vary due to differences between estimated and realized power prices as well as customer demand satisfied by Ameren Illinois, which will be affected by changes in customers’ elections to use Ameren Illinois or an alternative retail electric supplier for their energy needs. Because of the power procurement riders, the difference between actual purchased power costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. These pass-through costs do not affect Ameren Illinois’ net income, as any change in costs are offset by a corresponding change in revenues. Also, largely due to the capacity price set by the April 2023 MISO auction, Ameren Missouri estimates decreases to capacity revenues and purchased power costs for the calendar year 2023, compared to 2022, of approximately $100 million. Ameren Missouri sells nearly all of its capacity to the MISO and purchases the capacity it needs to supply its native load sales from the MISO. Capacity revenues and purchased power costs are a 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.

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•Ameren Missouri’s next refueling and maintenance outage at its Callaway Energy Center is scheduled for the fall of 2023. 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. Ameren Missouri expects to incur approximately $40 million in maintenance expenses related to the fall 2023 outage. During an outage, depending on the availability of its other generation sources and the market prices for power, Ameren Missouri’s purchased power costs may increase and the amount of excess power available for sale may decrease versus non-outage years. Changes in purchased power costs and excess power available for sale are included in the FAC, which results in limited impacts to earnings. In addition, Ameren Missouri may incur increased non-nuclear energy center maintenance costs in non-outage years.

•In December 2021, Ameren Missouri filed a motion with the United States District Court for the Eastern District of Missouri to modify a September 2019 remedy order issued by the district court to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The March ~~31,~~30, 2024 compliance date contained in the district court’s September 2019 remedy order remains in effect unless extended by the district court. In 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISO, and design and procurement activities necessary to complete the upgrades are underway. Ameren Missouri expects to complete the upgrades by mid-2025. In 2022, the FERC approvedRush Island Energy Center began operating as a system support resource ~~agreement, which became effective as of~~on September 1, 2022. ~~The~~In 2023, the MISO extended the system support resource designation for the Rush Island Energy Center through August 2024, and in July 2023, an agreement between Ameren Missouri and the MISO was filed with the FERC for approval that details the manner of continued operation for ~~a system support resource~~the Rush Island Energy Center that results in operating during peak demand times and emergencies. The system support resource designation and the related agreement are subject to annual renewal and revision. The FERC is under no deadline to issue an order. The transmission upgrade projects have been approved by the MISO, and construction activities necessary to complete the upgrades are underway. Ameren Missouri expects to complete the last of the upgrades by mid-2025. In ~~September 2022,~~August 2023, Ameren Missouri requested the district court to extend the March 30, 2024 compliance date to October 15, 2024, at which point Ameren Missouri proposes to retire the Rush Island Energy ~~Center began operating consistent with the system support resource agreement.~~Center. In addition, in October 2022, the FERC established hearing and settlement procedures in response to an August 2022 request from Ameren Missouri for recovery of non-energy costs under the related MISO tariff. In May 2023, a settlement agreement between Ameren Missouri and certain intervenors in the non-energy costs proceeding at the FERC, which provides for recovery of substantially all of Ameren Missouri’s requested non-energy costs through August 2023, was filed with the FERC for approval. The FERC is under no deadline to issue an ~~order related to this proceeding.~~order. Revenues and costs under the MISO tariff are included in the FAC. The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISO determination of the Rush Island Energy Center as a system support resource or the FERC’s approval. The district court is under no deadline to issue a ruling modifying the remedy order. For additional information on the NSR and Clean Air Act litigation, see Note 9 – Commitments and Contingencies under Part I, Item 1, of this report. In February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center, including potential impacts on the reliability and cost of Ameren Missouri’s service to its customers; Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement; and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement of the Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. ~~Since December 31, 2021,~~In Ameren ~~and Ameren Missouri classified~~Missouri’s last electric service regulatory rate review, the ~~remaining net book value of~~MoPSC staff recommended a lower rate base for the Rush Island Energy Center ~~as plant~~claiming imprudent actions by Ameren Missouri. While the nonunanimous stipulation and agreement approved in that regulatory rate review by the June 2023 MoPSC electric rate order did not specify any rate base disallowance, it did not preclude parties to ~~be abandoned, net, within “Property, Plant, and Equipment, Net” on Ameren’s and~~the agreement from raising issues regarding the prudence of Ameren Missouri’s ~~balance sheets.~~actions and decisions with regard to the energy center in future proceedings. As part of the assessment of any potential future abandonment loss, consideration will be given to rate and securitization orders issued by the MoPSC to Ameren Missouri and to orders issued to other Missouri utilities with similar facts.

•Pursuant to Illinois state law, Ameren Missouri’s natural gas-fired energy centers in Illinois are subject to limits on emissions, including CO2 and NOx, equal to their unit-specific average annual emissions from 2018 through 2020, for any rolling twelve-month period through 2029. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure of the Venice Energy Center by 2029. The reductions could also limit the operations of Ameren Missouri’s other four natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to certain conditions, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service.

•Ameren Missouri and Ameren Illinois continue to make infrastructure investments and expect to seek increases to electric and natural gas rates to recover the cost of investments and earn an adequate return. Ameren Missouri and Ameren Illinois will also seek new, or to maintain existing, 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, including limited economic growth in their service territories, increasing inflation, higher cost of debt, customer conservation efforts, the impacts of additional customer energy-efficiency programs, and increased customer use of increasingly cost-effective advancements in innovative energy technologies, including private generation and energy storage. However, over the long-term, we expect the decreased demand to be partially offset by

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increased demand resulting from increased electrification of the economy and as a means to address economy-wide CO2 emission concerns. We expect that increased investments, including expected future investments for environmental compliance, system reliability improvements, and new generation sources, will result in rate base and revenue growth but also higher depreciation and financing costs.

Liquidity and Capital Resources

•Ameren Missouri’s preferred resource plan is included in its 2022 Change to the 2020 IRP. In connection with this plan, Ameren is targeting net-zero carbon emissions by 2045, as well as a 60% reduction by 2030 and an 85% reduction by 2040 based on 2005 levels.

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Ameren’s goals include both direct emissions from operations (scope 1), as well as electricity usage at Ameren buildings (scope 2), including other greenhouse gas emissions of methane, nitrous oxide, and sulfur hexafluoride. Achieving these goals will be dependent on a variety of factors, including cost-effective advancements in innovative clean energy technologies and constructive federal and state energy and economic policies. The 2022 Change to the 2020 IRP includes, among other things, the following:

•the continued implementation of customer energy-efficiency programs;

•expanding renewable sources by adding 2,800 MWs of renewable generation by 2030, 400 MWs of battery storage by 2035, and a total of 4,700 MWs of renewable generation and 800 MWs of battery storage by 2040. These amounts include the solar generation projects discussed below;

•adding 1,200 MWs of natural gas-fired combined cycle generation by 2031, with plans to switch to hydrogen fuel and/or blend hydrogen fuel with natural gas and install carbon capture technology if these technologies become commercially available at a reasonable cost;

•adding 1,200 MWs of additional clean dispatchable generation by 2043;

•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;

•extending the retirement date of the coal-fired Sioux Energy Center from 2028 to 2030 to ensure reliability during the transition to clean energy ~~generation, which is subject to the approval of a change in the asset’s depreciable life by the MoPSC in Ameren Missouri’s 2022 electric service regulatory rate review;~~generation;

•accelerating the retirement date of the Rush Island coal-fired energy center to 2025;

•retiring the Meramec coal-fired energy center at the end of its useful life, ~~in 2022,~~ which was completed in December 2022;

•retiring the generating units at the Labadie coal-fired energy center at the end of their useful lives (two generating units by 2036 and the other two by 2042);

•accelerating the retirement date of the Venice natural gas-fired energy center to 2029; and

•retiring Ameren Missouri’s other natural gas-fired energy centers in Illinois by 2040.

Ameren Missouri’s plan could be affected by, among other factors: Ameren Missouri’s ability to obtain CCNs from the MoPSC, and any other required approvals for the addition of renewable resources or natural gas-fired combined cycle generation, retirement of energy centers, and new or continued customer energy-efficiency programs; the ability to enter into agreements for renewable or natural gas-fired combined cycle generation and acquire or construct that generation at a reasonable cost; the ability of suppliers, contractors, and developers to meet contractual commitments and timely complete projects, which is dependent upon the availability of necessary labor, materials, and equipment, ~~including those that are affected by the disruptions in the global supply chain caused by the COVID-19 pandemic,~~ geopolitical conflict, or government actions, among other things; changes in the scope and timing of projects; the ability to qualify for, and use or transfer, federal production or investment tax credits; the cost of wind, solar, and other renewable generation and battery storage technologies; the cost of natural gas or hydrogen CT technologies; the ability to maintain system reliability during and after the transition to clean energy generation; new and/or changes in environmental regulations, including those related to CO2 and other greenhouse gas emissions; energy prices and demand; Ameren Missouri’s ability to obtain necessary rights-of-way, easements, and transmission interconnection agreements at an acceptable cost and in a timely fashion, the inability to earn an adequate return on invested capital; and the ability to raise capital on reasonable terms. The next integrated resource plan ~~is expected to~~will be filed in September 2023.

•Missouri law allows Missouri electric utility companies to petition the MoPSC for a financing order to authorize the issuance of securitized utility tariff bonds to finance the cost of retiring electric generation facilities before the end of their useful lives. In connection with the planned accelerated retirement of the Rush Island Energy Center due to the NSR and Clean Air Act Litigation discussed above, Ameren Missouri expects to seek approval from the MoPSC as early as the fourth quarter of 2023, to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds.

•During 2022 and 2023, Ameren Missouri, and certain subsidiaries of Ameren Missouri, entered into agreements to acquire and/or construct various solar generation ~~facilities. The following table provides information~~facilities, with ~~respect to each solar generation facility:~~

~~Boomtown Solar Project(a)~~

~~Huck Finn Solar Project(b)~~

~~Vandalia Solar Project(c)~~

~~Agreement date~~

~~February 2022~~

~~June 2022~~

~~September 2022~~

~~Agreement type~~

~~Build-transfer~~

~~Self-build(d)~~

~~Developer~~

~~Invenergy Renewables, LLC~~

~~EDF Renewables, Inc.~~

~~Ameren Missouri(d)~~

~~Facility size~~

~~150-MW~~

~~200-MW~~

~~50-MW~~

~~Location~~

~~Southeastern Illinois~~

~~Central Missouri~~

~~Status of MoPSC CCN~~

~~Approved April 2023~~

~~Approved February 2023~~

~~Expect to file by mid-2023~~

~~Status of FERC approval of acquisition~~

~~Expect to request by mid-2023~~

~~Received March 2023~~

~~(e)~~

~~Expected completion date~~

~~As early as fourth quarter 2024(f)(g)~~

~~As early as fourth quarter 2024(g)~~

~~As early as mid-2025(f)~~

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~~(a)The Boomtown Solar Project is expected to support Ameren Missouri’s transition to renewable energy generation and serve customers under the Renewable Solutions Program.~~

~~(b)~~The Huck Finn Solar project is expected to support Ameren Missouri’s compliance with the state of Missouri’s requirement of achieving 15% of retail sales from renewable energy sources, of which 2% must be derived from solar energy sources.

~~(c)The Vandalia Solar Project is expected to support Ameren Missouri’s transition to renewable energy generation.~~

~~(d)Ameren Missouri entered into an engineering, supply, and construction agreement to construct the Vandalia Solar Project.~~

~~(e)Because Ameren Missouri will develop and construct the Vandalia Solar Project, there is no acquisition requiring FERC approval.~~

~~(f)Expected completion dates are dependent on the timing of~~various regulatory ~~approvals.~~

~~(g)Expected completion dates are dependent on the impact of potential sourcing issues discussed below.~~

approvals pending. All of the solar ~~projects above~~generation facilities are aligned with the 2022 Change to the 2020 IRP discussed above, and ~~are subject to certain conditions, including approval by the FERC for the Boomtown Solar Project and the issuance of a CCN by the MoPSC for the Vandalia Solar Project. Capital~~capital expenditures related to these facilities are included in Ameren’s and Ameren Missouri’s expected capital investments discussed below.

•Ameren ~~Missouri's~~Missouri’s 2022 Change to the 2020 IRP targets cleaner and more diverse sources of energy generation, including solar

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generation. While rights to acquire and/or construct the solar facilities discussed above were secured through agreements, supply chain disruptions, including solar panel shortages and increasing material costs as a result of government tariffs and other factors, could affect the costs, as well as the timing, of these projects and other solar generation projects. The supply of solar panel components to the United States was significantly disrupted as a result of an investigation initiated by the United States Department of Commerce in late March 2022, which could result in significant tariffs on solar panel components imported from four Southeast Asian countries. The investigation is in response to a petition, which alleged that Chinese solar manufacturers shifted solar panel component manufacturing to these countries to avoid tariffs imposed on imports from China. In December 2022, the United States Department of Commerce issued a preliminary determination, finding that all exporters and producers of solar panel components from the four Southeast Asian countries, with a few exceptions, have been circumventing tariffs imposed on imports from China. As a result of the preliminary determination, importers and exporters may avoid the imposition of increased tariffs by certifying to the United States Department of Commerce that the entry of solar panel components into the United States are not subject to the investigation or that they fall within the scope of the 24-month waiver of tariffs discussed below. Failure to submit the applicable certifications, or denial of the submitted certifications by the United States Department of Commerce, could result in increased tariffs on solar panel components that are subject to the investigation and entered the United States on or after April 1, 2022. The United States Department of Commerce is expected to issue a final determination by mid-August 2023. Additionally, certain solar panel components from China have been subject to detention by the United States Customs and Border Protection Agency as a result of the Uyghur Forced Labor Prevention Act that became effective in June 2022. Also, in June 2022, President Biden authorized the United States Department of Energy to use the Defense Production Act to rapidly expand American manufacturing of five critical clean energy technologies, including solar panel components. President Biden also took executive action to temporarily lift certain tariffs on solar panel components imported from the four Southeast Asian countries under investigation by the United States Department of Commerce for 24 months in order to allow the United States access to a sufficient supply of solar panel components to meet electricity generation needs while domestic manufacturing scales up. Any future tariffs or other outcomes resulting from the investigation by the United States Department of Commerce or actions by the United States Customs and Border Protection Agency could affect the cost and the availability of solar panel components and the timing and amount of Ameren ~~Missouri's~~Missouri’s estimated capital expenditures associated with solar generation investments.

•Through 2027, we expect to make significant capital expenditures to improve our electric and natural gas utility infrastructure, with a major portion directed to our transmission and distribution systems. We estimate that we will invest up to $20.5 billion (Ameren Missouri – up to $10.8 billion; Ameren Illinois – up to $9.5 billion; ATXI – up to $0.2 billion) of capital expenditures during the period from 2023 through 2027. These planned investments are based on the assumption of continued constructive regulatory frameworks. Ameren’s and Ameren Missouri’s estimates include $2.5 billion of renewable generation investments through 2027 consistent with investments outlined in Ameren Missouri’s 2022 Change to the 2020 IRP. Ameren’s estimate also includes $0.8 billion of capital expenditures through 2027 related to projects assigned to Ameren pursuant to the first tranche of projects under the MISO’s long-range transmission planning roadmap discussed below.

•As a result of major storms experienced throughout our service territories in late June and July 2023, Ameren Missouri and Ameren Illinois expect capital expenditures related to restoration costs of approximately $65 million to $80 million and $60 million to $75 million, respectively.

•In 2021, the MISO issued a report outlining a preliminary long-range transmission planning roadmap of projects through 2039, which considers the rapidly changing generation mix within MISO resulting from significant additions of renewable generation, actual and expected generation plant closures, and state mandates or goals for clean energy or carbon emissions reductions. In July 2022, the MISO approved the first tranche of projects under the first phase of 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. Construction on the Ameren projects is expected to begin in 2025, with completion dates expected near the end of this decade. The MISO initiated requests for proposals for additional first tranche competitive bid projects in December 2022, ~~with proposals due in May~~June 2023, ~~and is expected to initiate additional requests for proposals in June~~ and July 2023, with proposals due in May 2023, November 2023, and October 2023, respectively. These competitive-bid projects are estimated by the MISO to cost approximately $0.7 billion and are expected to be awarded between late-2023 and mid-2024. In November 2022, the MISO released plans for a second tranche of projects and began the process of identifying a list of projects for consideration under this tranche. Ameren expects the second tranche of

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projects to be approved in the first half of 2024. In July 2022, a group of industrial customers filed a complaint with the FERC, challenging provisions of a MISO tariff that exclude regional transmission projects from the MISO’s competitive bid process based on state laws related to the right of first refusal, which provide an incumbent utility the right to build, maintain, and own transmission lines located within its service territory. The complaint seeks to require MISO to revise its tariff to prohibit the application of state laws related to the right of first refusal in the MISO’s long-range transmission planning and require projects to be bid on a competitive basis, to the maximum extent possible. It also is asking for refunds related to any costs under the tariff that would not comply with the sought-after revisions. The FERC is under no deadline to issue an order in this proceeding.

•In July 2022, an Illinois law prohibiting the state’s oversight of certain electric utilities’ choice of RTO membership ceased to be effective. Given the change in law and the high prices resulting from MISO’s April 2022 capacity auction, the ICC issued an order requiring

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Ameren Illinois to perform a cost-benefit study of continued participation in the MISO compared to participation in PJM Interconnection LLC, another RTO. In July 2023, Ameren Illinois filed its cost-benefit study with the ICC. The cost-benefit study ~~will examine~~examined the impacts of participation in each RTO, including reliability, resiliency, affordability, and environmental impacts, among other things, for a period of five to 10 years, beginning June 2024. The ~~ICC order requires Ameren Illinois to file~~study concluded that continued participation in the ~~study by July 2023. A 30-day comment period will follow.~~MISO was prudent and more cost-beneficial than participation in PJM Interconnection LLC. The ICC is under no obligation to issue an order related to the cost-benefit study.

•Environmental regulations, including those related to CO2 emissions, or other actions taken by the EPA or state regulators, or requirements that may result from the NSR and Clean Air Act Litigation, ~~discussed in Note 9 – Commitments and Contingencies under Part I, Item 1, of this report,~~ could result in significant increases in capital expenditures and operating costs. Regulations can be reviewed and repealed, and replacement or alternative regulations can be proposed or adopted by the current federal administration, including the EPA. See Note 9 – Commitments and Contingencies under Part I, Item 1, of this report, for additional information on environmental matters, including the NSR and Clean Air Act litigation. The ultimate implementation of any of these new regulations, as well as the timing of any such implementation, is uncertain. However, the individual or combined effects of existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of some of Ameren Missouri’s coal and natural gas-fired energy centers. Ameren Missouri’s capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances, as well as regulatory lag. The cost of Ameren Illinois’ purchased power and natural gas purchased for resale could increase. However, Ameren Illinois expects that these costs would be recovered from customers with no material adverse effect on its results of operations, financial position, or liquidity. Ameren’s and Ameren Missouri’s earnings could benefit from increased investment to comply with environmental regulations if those investments are reflected and recovered on a timely basis in customer rates.

•The Ameren Companies have multiyear credit agreements that cumulatively provide $2.6 billion of credit through December 2027, subject to a 364-day repayment term for Ameren Missouri and Ameren Illinois, with the option to seek incremental commitments to increase the cumulative credit provided to $3.2 billion. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report and Note 4 – Short-term Debt and Liquidity under Part II, Item 8, in the Form 10-K for additional information regarding the Credit Agreements. See Note 5 – ~~Long-Term~~Long-term Debt and Equity Financings under Part II, Item 8, in the Form 10-K for long-term debt maturities from 2023 to 2027 and beyond at Ameren (parent), Ameren Missouri, Ameren Illinois, and ~~ATXI.~~ATXI and see Note 4 – Long-term Debt and Equity Financings under Part I, Item 1, of this report for principal payments made on long-term debt during 2023 through the date of this report. 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 ~~rather than market-purchased shares,~~ to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 2027. Ameren expects these equity issuances to total about $100 million annually. In addition, Ameren has an ATM program under which Ameren may offer and sell from time to time common stock, which includes the ability to enter into forward sales agreements, subject to market conditions and other factors. As of ~~April~~June 30, 2023, Ameren ~~has~~had multiple forward sale agreements ~~outstanding~~that could be settled under the ATM program with various counterparties relating to ~~3.8~~4.3 million shares of common stock. Ameren expects to settle approximately $300 million of the forward sale agreements with physical delivery of 3.2 million shares of common stock by December 31, 2023. Also, Ameren plans to issue approximately $500 million of equity each year from 2024 to 2027, in addition to issuances under the DRPlus and employee benefit plans. As of ~~March 31,~~June 30, 2023, Ameren had approximately ~~$980~~$910 million of common stock available for sale under the ATM program, which takes into account the forward sale agreements in effect as of ~~March 31,~~June 30, 2023. Ameren expects its equity to total capitalization to be about 45% ~~through~~by December 31, 2027, with the long-term intent to support solid investment-grade credit ratings. Ameren Missouri and Ameren Illinois expect to fund cash flow needs through debt issuances, adjustments of dividends to Ameren (parent), and/or capital contributions from Ameren (parent).

•The IRA was enacted in August 2022, and includes various income tax provisions, among other things. The law extends federal production and investment tax credits for projects beginning construction through 2024 and allows for a 10% adder to the production and investment tax credits for siting projects at existing energy communities as defined in the law, which includes sites previously used for coal-fired generation. The law also creates clean energy tax credits for projects placed in service after 2024. The clean energy tax

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credits will apply to renewable energy production and investments, along with certain nuclear energy production, and will be phased out beginning in 2033, at the earliest. The phase-out is triggered when greenhouse gas emissions from the electric generation industry are reduced by at least 75% from the annual 2022 emission rate or at the beginning of 2033, whichever is later. The law allows for transferability to an unrelated party for cash of up to 100% of certain tax credits generated after 2022. In addition, the new law imposes a 15% minimum tax on adjusted financial statement income, as defined in the law, for corporations whose average annual adjusted financial statement income exceeds $1 billion for three consecutive preceding tax years effective for tax years beginning after

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December 31, 2022. Once a corporation exceeds this three-year average annual adjusted financial statement income threshold, it will be subject to the minimum tax for all future tax years. Additional regulations, interpretations, amendments, or technical corrections to or in connection with the IRA are expected to be issued by the IRS or United States Department of Treasury, which may impact the timing of when the 15% minimum tax becomes applicable for Ameren as discussed below.

•As of ~~March 31,~~June 30, 2023, Ameren had ~~$184~~$198 million in tax benefits from federal and state income tax credit carryforwards and $48 million in tax benefits from federal and state net operating loss carryforwards, which will be utilized in future periods. Future expected income tax payments are based on expected taxable income, available income tax credit and net operating loss carryforwards, and current tax law. Expected taxable income is affected by expected capital expenditures, when property, plant, and equipment is placed in-service or retired, and the timing of regulatory reviews, among other things. Ameren expects federal income tax payments at the required minimum levels from 2023 to 2027 resulting from the anticipated use of existing production tax credits generated by Ameren Missouri’s High Prairie Renewable and Atchison Renewable energy centers, existing income tax credit and net operating loss carryforwards, and outstanding refunds. Based on its preliminary calculations, Ameren does not expect to be subject to the 15% minimum tax on adjusted financial statement income imposed by the IRA in 2023 and 2024. Ameren expects annual federal income tax payments, including payments related to the 15% minimum tax pursuant to the IRA, to be immaterial through 2027.

The above items could have a material impact on our results of operations, financial position, and liquidity. Additionally, in the ordinary course of business, we evaluate strategies to enhance our results of operations, financial position, and liquidity. These strategies may include acquisitions, divestitures, opportunities to reduce costs or increase revenues, and other strategic initiatives to increase Ameren’s shareholder value. We are unable to predict which, if any, of these initiatives will be executed. The execution of these initiatives may have a material impact on our future results of operations, financial position, or liquidity.

REGULATORY MATTERS

See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

There have been no material changes to the quantitative and qualitative disclosures about interest rate risk, credit risk, commodity price risk, investment price risk, and commodity supplier risk included in the Form 10-K, except as discussed below. See Item 7A under Part II of the Form 10-K for a more detailed discussion of our market risk.

Ameren Missouri received a planned ~~deliveries~~delivery of enriched uranium from a Russian supplier in the spring of 2023. The planned delivery concluded the nuclear fuel supply agreement with this Russian supplier ~~has been fulfilled in its entirety, and Ameren Missouri does not have~~with no future deliveries planned with any ~~outstanding supply contracts with~~ Russian suppliers. Ameren Missouri has ~~inventories~~sufficient inventory and supply contracts with non-Russian suppliers that adequately meet all of the nuclear fuel needs of the Callaway Energy Center through the 2026 refueling reload.

ITEM 4. CONTROLS AND PROCEDURES.

(a)Evaluation of Disclosure Controls and Procedures

As of ~~March 31,~~June 30, 2023, 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 ~~March 31,~~June 30, 2023, the principal executive officer and the principal financial officer of each of the Ameren Companies concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in such registrant’s reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to its management, including its principal executive officer and its principal financial officer, to allow timely decisions regarding required disclosure.

(b)Changes in Internal Controls over Financial Reporting

There has been no change in any of the Ameren Companies’ internal control over financial reporting during their most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, each of their internal control over financial reporting.

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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,

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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.

There have been no material changes to the risk factors disclosed in Part I, Item 1A, Risk Factors in 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 ~~January~~April 1, 2023, to ~~March 31,~~June 30, 2023.

ITEM 5. OTHER INFORMATION.

Insider Adoption or Termination of Trading Arrangements

During the fiscal quarter ended June 30, 2023, none of our directors or officers informed us of the adoption or termination of a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as those terms are defined in Regulation S-K, Item 408.

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ITEM 6. EXHIBITS.

The documents listed below are being filed or have previously been filed on behalf of the Ameren Companies and are incorporated herein by reference from the documents indicated and made a part hereof. Exhibits not identified as previously filed are filed herewith.

Exhibit
Designation

Registrant(s)

Nature of Exhibit

Previously Filed as Exhibit to:

Instruments Defining Rights of Security Holders, Including Indentures

4.1

Ameren
Ameren ~~Missouri~~Illinois

Supplemental Indenture , dated as of May 1, 2023, to the Ameren ~~Missouri~~ Illinois Mortgage ~~dated February 1, 2023,~~ for ~~5.45%~~4 .9 5% First Mortgage Bonds due ~~2053~~20 3 3

~~March 13,~~May 31, 2023 Form 8-K, Exhibit 4.2, File No. ~~1-14756~~1-3672

Material Contracts

10.1

Ameren Ameren Missouri

First Amendment, dated as of April 19, 2023, to Amended and Restated Credit Agreement, dated as of December 6, 2022, by and among Ameren, Ameren Missouri and JPMorgan Chase Bank, N.A., as agent and the lenders party thereto

10.2

Ameren Ameren Illinois

First Amendment, dated as of April 19, 2023, to Amended and Restated Credit Agreement, dated as of December 6, 2022, by and among Ameren, Ameren Illinois and JPMorgan Chase Bank, N.A., as agent and the lenders party thereto

Rule 13a-14(a) / 15d-14(a) Certifications

31.1

Ameren

Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren

31.2

Ameren

Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren

31.3

Ameren Missouri

Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Missouri

31.4

Ameren Missouri

Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Missouri

31.5

Ameren Illinois

Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Illinois

31.6

Ameren Illinois

Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Illinois

Section 1350 Certifications

32.1

Ameren

Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren

32.2

Ameren Missouri

Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Missouri

32.3

Ameren Illinois

Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Illinois

Interactive Data Files

101.INS

Ameren Companies

Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document

101.SCH

Ameren Companies

Inline XBRL Taxonomy Extension Schema Document

101.CAL

Ameren Companies

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB

Ameren Companies

Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE

Ameren Companies

Inline XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF

Ameren Companies

Inline XBRL Taxonomy Extension Definition Document

104

Ameren Companies

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

The file number references for the Ameren Companies’ filings with the SEC are: Ameren, 1-14756; Ameren Missouri, 1-2967; and Ameren Illinois, 1-3672.

Each registrant hereby undertakes to furnish to the SEC upon request a copy of any long-term debt instrument not listed above that such registrant has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.

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SIGNATURES

Pursuant to the requirements of the Exchange Act, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.



AMEREN CORPORATION (Registrant)

/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)


UNION ELECTRIC COMPANY (Registrant)

/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)


AMEREN ILLINOIS COMPANY (Registrant)

/s/ Michael L. Moehn
Michael L. Moehn Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date: ~~May 5,~~August 3, 2023

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	March 31, 2023						March 31, 2022
	Ameren		Ameren Missouri				Ameren Illinois	Ameren		Ameren Missouri		Ameren Illinois
Investing:
Accrued capital expenditures	$	298	$	153	$	138		$	345	$	194	$	147

Net realized and unrealized gain/(loss) – nuclear decommissioning trust fund	54		54		—			(71)		(71)		—
Return of investment in industrial development revenue bonds(a)	240		240		—			—		—		—
Financing:
Issuance of common stock for stock-based compensation	$	37	$	—	$	—		$	31	$	—	$	—
Issuance of common stock under the DRPlus	7		—		—			8		—		—
Termination of a financing obligation(a)	240		240		—			—		—		—