ML22349A635
| ML22349A635 | |
| Person / Time | |
|---|---|
| Site: | Callaway  |
| Issue date: | 12/15/2022 |
| From: | Ameren Missouri, Union Electric Co |
| To: | Office of Nuclear Reactor Regulation, Office of Nuclear Security and Incident Response |
| Shared Package | |
| ML22349A623 | List: |
| References | |
| ULNRC-06788 | |
| Download: ML22349A635 (1) | |
Text
ULNRC-06788 0 Page 1 of 90 Ameren Missouri (Union Electric Company)
Callaway Plant 10-Q FILED 06/30/2022 89 pages follow this cover sheet
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 June 30, 2022 OR Transition report pursuant to Section 1 3 or I 5(d) of the Securities Exchange Act of I 934 for the transition period from to g
Ameren Ameren MISSOURI ILLINOIS Exact name of registrant as specified in its charter; Commission State of Incorporation; IRS Employer File Number Address and Telephone Number ldentiflcation 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 Executive Drive Collinsville, Illinois 62234 (618) 343-8150 Securities Registered Pursuant to Section 1 2(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
Indicate by check mark whether the registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) ofthe 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 No Union Electric Company Yes No Ameren Illinois Company Yes No Li Indicate by check mark whether each registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T ( 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Ameren Corporation Yes No Li Union Electric Company Yes No Li Ameren Illinois Company Yes No Li 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 definitions of large accelerated filer, accelerated filer, smaller reporting company, and emerging growth company in Rule 12b-2 ofthe Exchange Act.
Ameren Corporation Large accelerated filer Accelerated filer Li Non-accelerated filer Li Smaller reporting company Li Emerging growth company Li Union Electric Company Large accelerated filer Li Accelerated filer Li Non-accelerated filer Smaller reporting company Li Emerging growth company Li Ameren Illinois Company Large accelerated filer Li Accelerated filer Li Non-accelerated filer Smaller reporting company Li Emerging growth company Li If an emerging growth company, indicate by check mark ifthe 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 Li Union Electric Company Li Ameren Illinois Company Li Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 ofthe Exchange Act).
Ameren Corporation Yes Li No Union Electric Company Yes No Ameren Illinois Company Yes No The number of shares outstanding of each registrants classes of common stock as of July 29, 2022, was as follows:
Registrant Title of each class of common stock Shares outstanding Ameren Corporation Common stock, $0.01 par value per share 258,370,605 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 ofthe 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.
TABLE OF CONTENTS Page GIossat of Terms and Abbreviations forward-looking Statements PART I. Financial Information Item I . Financial Statements (Unaudited).
Ameren Corporation 4 Consolidated Statement of Income and Comprehensive Income 4 Consolidated Balance Sheet Consolidated Statement of Cash Flows Consolidated Statement of Shareholders Ecuity Z Union Electric Company (dibla Ameren Missouri)
Consolidated Statement of Income consolidated Balance Sheet 9 Consolidated Statement of Cash Flows, 1Q Consolidated Statement of Shareholders Equity jj.
Ameren Illinois Company (dlbla Ameren Illinois) 12 Statement of Income Balance Sheet Statement of Cash Flows Statement of Shareholders Equity Note I Summary of Significant Accounting Policies Note 2. Rate and Regulatory Matters 11 Note 3. Short-term Debt and Liquidity Note 4. Long-term Debt and Equity Financings 21.
Note 5. Other Income, Net 22 Note 6. Derivative Financial Instruments Note 7. Fair Value Measurements Note 8. Related-party Transactions 21 Note 9. Commitments and Contingencies Note 10. Callaway Energy Center Note 11. Retirement Benefits Note 12. lncomeTaxes 34 Note 13. Supplemental Information Note 14. Segment Information, 37 Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations Item 3. Quantitative and Qualitative Disclosures About Market Risk Item 4. Controls and Procedures Z4 PART II. Other Information Item 1 . Legal Proceeding 14 Item IA. Risk Factors 14 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds Item 6. Exhibits Jgnatires 77
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 ofAmeren Corporation are named specifically as their various business activities are discussed.
Refer to the Form I 0-K for a complete listing of glossary terms and abbreviations. Only new or significantly changed terms and abbreviations are included below.
2020 IRP Integrated Resource Plan, a long-term nonbinding plan that Ameren Missouri filed with the MoPSC in September 2020.
2022 Change to the 2020 IRPAchangetoAmeren Missouris 2020 IRP filed with the MoPSC in June 2022 reflecting certain modifications to Ameren Missouris preferred approach for meeting its customers projected long-term energy needs in a cost-effective manner while maintaining system reliability and achieving a goal of net-zero CO2 emissions by 2045.
Form 10-K The combined Annual Report on Form JO-K for the year ended December 3J 202J filed by the Ameren Companies with the SEC.
PISA Plant-in-service accounting regulatory mechanism, a mechanism under Missouri law that permits electric utilities to defer and recover 85% of the depreciation expense and earn a return at the applicable WACC on rate base for certain property, plant, and equipment placed in service, and not included in base rates, subject to MoPSC prudence reviews. The rate base on which the return is calculated incorporates qualifying capital expenditures not included in base rates, as well as changes in total accumulated depreciation excluding retirements and plant-related deferred income taxes. The regulatory asset for accumulated PISA deferrals earns a return at the applicable WACC. The PISA is effective through December 2028, unless Ameren Missouri requests and receives MoPSC approval of an extension through December 2033.
QTD Three months ended June 30.
Smart Energy Plan Ameren Missouris plan to upgrade its electric grid through at least 2026. Planned upgrades include investments to improve reliability and accommodate more renewable energy.
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 J 995, 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 JO-K and in this report, 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 Court for the Eastern District of Missouri regarding its September 2OJ 9 remedy order for the Rush Island Energy Center, the MoPSC staff review of the planned Rush Island Energy Center retirement, Ameren Missouris electric service regulatory rate review filed with the MoPSC in August 2022, the July 2020 appeal filed by Ameren Missouri, Ameren Illinois, and ATXI challenging the refund period related to the FERCs May 2020 order determining the allowed base ROE under the MISO tariff, the July 2020 appeal filed by Ameren Missouri, Ameren Illinois, and ATXI challenging the FERCs rehearing denials in the transmission formula rate revision cases, Ameren Illinois electric distribution service rate reconciliation request filed with the ICC in April 2022, and Ameren Illinois annual electric energy-efficiency formula rate update filed with the ICC in June2022;
. the length and severity of the COVID-J 9 pandemic, and its impacts on our business continuity plans and our results of operations, financial position, and liquidity, including but not limited to changes in customer demand resulting in changes to sales volumes; customers payment for our services; the health, welfare, and availability of our workforce and contractors; supplier disruptions; delays in the completion of construction projects, which could impact our expected capital expenditures and rate base growth; changes in how we operate our business; and our ability to access the capital markets on reasonable terms and when needed;
. the effect ofAmeren Illinois use of the performance-based formula ratemaking framework for its electric distribution service under the IEIMA, which will establish and allow 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 ofAmeren Illinois election to either utilize traditional regulatory rate reviews or MYRPs for electric distribution service ratemaking effective for rates beginning in 2024; I
. the effect on Ameren Missouri of any customer rate caps or limitations to increases to the electric service revenue requirement pursuant to Ameren Missouris election to use the PISA;
. 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, regulations, interpretations, or rates, and challenges to the tax positions taken by the Ameren Companies, if any, as well as resulting effects on customer rates;
. 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; e the effectiveness ofAmeren Missouris customer energy-efficiency programs and the related revenues and performance incentives earned under its MEEIA programs;
. Ameren Illinois ability to achieve the performance standards applicable to its electric distribution business and electric customer energy-efficiency goals and the resulting impact on its allowed ROE;
. 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 cost and availability of fuel, such as low-sulfur coal, natural gas, and enriched uranium used to produce electricity; the cost and availability of purchased power, zero emission credits, renewable energy credits, emission allowances, and natural gas for distribution; 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 offuel, including nuclearfuel assemblies from the one NRC-licensed supplier ofsuch assemblies forAmeren Missouris Callaway Energy Center;
. the cost and availability of transmission capacity for the energy generated by Ameren Missouris energy centers or required to satisfy Ameren Missouris energy sales; I
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;
. increased data security risks as a result of remote working arrangements for a significant portion of our workforce;
. the impact of cyberattacks 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;
. business and economic conditions, which have been affected by, and will be affected by the length and severity of, the COVID-19 pandemic, including the impact of such conditions on interest rates and inflation; 0
disruptions of the capital 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;
. the actions of credit rating agencies and the effects of such actions, including any impacts on our credit ratings that may result from the economic conditions ofthe COVID-19 pandemic;
. the inability of our counterparties to meet their obligations with respect to contracts, credit agreements, and financial instruments, including as they relate to the construction and acquisition of electric and natural gas utility infrastructure and the ability of counterparties to complete projects, which is dependent upon the availability of necessary materials and equipment, including those obligations that are affected by supply chain disruptions;
. the impact of weather conditions and other natural phenomena on us and our customers, including the impact of system outages and the level ofwind and solar resources; U
the construction, installation, performance, and cost recovery of generation, transmission, and distribution assets; U
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; U
the operation ofAmeren Missouris 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; U
Ameren Missouris 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; U
the impact of current environmental laws and new, more stringent, or changing requirements, including those related to NSR and C02, 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 ofAmeren Missouris 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; U
the impact of complying with renewable energy standards in Missouri and Illinois and with the zero emission standard in Illinois; U
Ameren Missouris ability to construct and/or acquire wind, solar, and other renewable energy generation facilities as well as natural gas-fired combined cycle energy centers, retire energy centers, and implement new or existing customer energy-efficiency programs, 2
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, related return, and, in the case of customer energy-efficiency programs, any lost margins in a timely manner, which is affected by the ability to obtain all necessary regulatory and project approvals, including certificates of convenience and necessity from the MoPSC or any other required approvals for the addition of renewable resources;
. the availability of federal production and investment tax credits related to renewable energy and Ameren Missouris ability to use such credits; the cost ofwind, solar, and other renewable generation and storage technologies; and our ability to obtain timely interconnection agreements with the MISC or other RTOs at an acceptable cost for each facility; a 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 constructive federal and state energy and economic policies with respect to those technologies; p
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; a the impact of negative opinions of us or our utility services that our customers, investors, legislators, regulators, or other stakeholders may have or develop, which could result from a variety offactors, 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; a the impact of adopting new accounting guidance; a the effects of strategic initiatives, including mergers, acquisitions, and divestitures; I
legal and administrative proceedings;
. 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, or other commodities, materials, or 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; and
. acts of sabotage, war, terrorism, or other intentionally disruptive acts.
New factors emerge from time to time, and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement. Given these uncertainties, undue reliance should not be placed on these forward-looking statements. Except to the extent required by the federal securities laws, we undertake no obligation to update or revise publicly any forward-looking statements to reflect new information or future events.
. 3
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 Six Months Ended June 30. June 30, 2022 2021 2022 2021 Operating Revenues:
Electric $ 1,513 $ 1,284 $ 2,831 $ 2,440 Natural gas 21 3 1 88 774 598 Total operating revenues I ,726 I 472 3,605 3,038 Operating Expenses:
Fuel 83 173 259 238 Purchased power 31$ 129 495 320 Natural gas purchased for resale 80 65 373 230 Other operations and maintenance 491 412 952 832 Depreciation and amortization 316 285 615 566 Taxes other than income taxes 129 122 271 250 Totaloperatingexpenses 1,417 1,186 2,965 2,436 Operating Income 309 286 640 602 Other Income, Net 62 49 122 95 lnterestCharges 126 96 230 196 Income Before Income Taxes 245 239 532 501 IncomeTaxes 36 31 70 58 Netlncome 209 208 462 443 Less: Net Income Attributable to Noncontrolling Interests 2 1 3 3 Net Income Attributable to Ameren Common Shareholders $ 207 $ 207 $ 459 $ 440 Netincome $ 209 $ 208 $ 462 $ 443 Other Comprehensive Income (Loss), Net of Taxes Pension and other postretirement benefit plan activity, net of income taxes of
$, $, $, and $, respectively (1) 1 Comprehensive Income 209 207 463 443 Less: Comprehensive Income Attributable to Noncontrolling Interests 2 1 3 3 Comprehensive Income Attributable to Ameren Common Shareholders $ 207 $ 206 $ 460 $ 440 Earnings per Common Share Basic $ 0.80 $ 0.81 $ 1.78 $ 172 Earnings per Common Share Diluted $ O8O $ 0.80 $ 1.77 $ t71 Weighted-average Common Shares Outstanding Basic 258.2 256.1 258.0 255.2 Weighted-average Common Shares Outstanding Diluted 259.4 257.2 259.2 256.5 The accompanying notes are an integral part of these consolidated financial statements.
4
AMEREN CORPORATION CONSOLIDATED BALANCE SHEET (Unaudited) (In millions, except per share amounts)
June 30, December 31, 2022 2021 ASSETS Current Assets:
Cash and cash equivalents $ 7$
Accounts receivable trade (less allowance for doubiful accounts of $30 and $29, respectively) 519 434 Unbilled revenue 400 301 Miscellaneous accounts receivable 81 85 Inventories 600 592 Mark-to-market derivative assets I 57 66 Current regulatory assets 333 319 Current collateral assets 222 66 Other current assets 77 97 Total current assets 2,396 1,968 Property, Plant, and Equipment, Net 30,086 29,261 Investments and Other Assets:
Nuclear decommissioning trust fund 957 I I 59 Goodwill 411 411 Regulatory assets 1,487 1,289 Pension and other postretirement benefits 808 756 Other assets 963 891 Total investments and other assets 4,626 4,506 TOTAL ASSETS $ 37,108 $ 35,735 LIABILITIES AND EQUITY Current Liabilities:
Current maturities of long-term debt $ 605 $ 505 Short-term debt 1,021 545 Accounts and wages payable 897 1,095 Current regulatory liabilities 241 113 Other current liabilities 824 568 Total current liabilities 3,588 2,826 Long-term Debt, Net I 2,985 I 2,562 Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and tax credits, net 3,614 3,499 Regulatory liabilities 5,727 5,848 Asset retirement obligations 774 757 Other deferred credits and liabilities 411 414 Total deferred credits and other liabilities 10,526 10,518 Commitments and Contingencies (Notes 2, 9, and 10)
Shareholders Equity:
Common stock, $01 par value, 400.0 shares authorized shares outstanding of 258.4 and 257.7, respectively 3 Other paid-in capital, principally premium on common stock 6,527 6,502 Retained earnings 3,336 3,182 Accumulated other comprehensive income 14 13 Total shareholders equity 9,880 9,700 Noncontrolling Interests I 29 I 29 Total equity 10,009 9,829 TOTAL LIABILITIES AND EQUITY $_ 37,108 $ 35,735 The accompanying notes are an integral part of these consolidated financial statements.
5
AMEREN CORPORATION CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) (In millions)
Six Months Ended June 30, 2022 2021 Cash Flows From Operating Activities:
Netincome $ 462 $ 443 Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization 665 596 Amortization of nuclear fuel 2$ 20 Amortization ofdebt issuance costs and premium/discounts 12 11 Deferred income taxes and investment tax credits, net 66 59 Allowance for equity funds used during construction (19) (16)
Stock-based compensation costs 12 11 Other 33 Changes in assets and liabilities:
Receivables (1 87) (92)
Inventories (8) (5)
Accounts and wages payable (87) (208)
Taxes accrued 94 104 Regulatory assets and liabilities (74) (441)
Assets, other (35) (36)
Liabilities, other 45 13 Pension and other postretirement benefits (32) 1 Counterparty collateral, net (103) (26)
Net cash provided by operating activities 872 436 Cash Flows From Investing Activities:
Capital expenditures (1,538) (1763)
Nuclear fuel expenditures (22) (4)
Purchases of securities nuclear decommissioning trust fund (122) (203)
Sales and maturities of securities nuclear decommissioning trust fund I 14 208 Other - 16 Net cash used in investing activities (1 ,552) (1760)
Cash Flows From Financing Activities:
Dividends on common stock (305) (282)
Dividends paid to noncontrolling interest holders (3)
Short-term debt, net 475 (59)
Issuances of long-term debt 524 1423 Issuances of common stock I7 258 Redemptions ofAmeren Illinois preferred stock (13)
Employee payrolltaxes related to stock-based compensation (16) (17)
Debt issuance costs (6) (13)
Other ------ - -
Net cash provided by financing activities 686 1290 Net change in cash, cash equivalents, and restricted cash 6 (34)
Cash, cash equivalents, and restricted cash at beginning ofyear 155 301 Cash, cash equivalents, and restricted cash at end of period $ 161 $ 267 The accompanying notes are an integral part of these consolidated financial statements.
6
AMEREN CORPORATION CONSOLIDATED STATEMENT OF SHAREHOLDERS EQUITY (Unaudited) (In millions, except per share amounts)
Three Months Ended Six Months Ended June 30, June 30, 2022 2021 2022 2021 Common Stock $ 3 $ 3 $ 3 $ 3 Other Paid-in Capital:
Beginning of period 6,507 6,295 6,502 6,179 Settlement of forward sale agreement through common shares issuance I 13 Shares issued under the ATM program 121 121 Shares issued under the DRPlus and 401(k) plan 12 12 25 24 Stock-based compensation activity 8 8 (1)
Other paid-in capital, end of period 6,527 6,436 6,527 6,436 Retained Earnings:
Beginning of period 3,282 2,850 3,182 2,757 Net income attributable to Ameren common shareholders 207 207 459 440 Dividends on common stock (1531 (1421 (2822 Retained earnings, end of period 3,336 2,915 3,336 2915 Accum ulated Other Corn prehensive Income:
Deferred retirement benefit costs, beginning of period 14 13 Change in deferred retirement benefit costs (1) 1 Deferred retirement benefit costs, end of period -
14 (1) 14 (1)
Total accumulated other comprehensive income, end of period 14 (1) (1)
Total Shareholders Equity $ 9,880 $ 9,353 $ 9,880 $ 9,353 Noncontrolling Interests:
Beginning of period 129 129 129 142 Net income attributable to noncontrolling interest holders 2 1 3 Dividends paid to noncontrolling interest holders (2) (1) (3) (3)
Redemptions ofAmeren Illinois preferred stock (13)
Noncontrolling interests, end of period 129 129 129 I 29 Total Equity ,$ 10,009 $ 9,482 $ 10,009 $ 9,482 Common stock shares outstanding at beginning of period 258.2 255.5 257.7 253.3 Shares issued under forward sale agreement I .6 Shares issued under the ATM program I .4 1.4 Shares issued under the DRPIus and 401 (k) plan 0.2 0.2 0.3 0.3 Shares issued for stock-based compensation 0.4 0.5 Common stock shares outstanding at end of period 258.4 257.1 258.4 257.1 Dividends per common share $ 0.59 $ 0.55 $ 1.18 $ 110 The accompanying notes are an integral part of these consolidated financial statements.
7
UNION ELECTRIC COMPANY (dibla AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF INCOME (Unaudited) (In millions)
Three Months Ended Six Months Ended June 30, June30, 2022 2021 2022 2021 Operating Revenues:
Electric $ 890 $ 789 $ 1,628 $ 1,430 Natural gas 29 20 109 83 Total operating revenues 91 9 809 1737 I 513 Operating Expenses:
Fuel 83 173 259 238 Purchasedpower 161 50 211 138 Natural gas purchased for resale 12 5 58 36 Otheroperations and maintenance 260 218 492 443 Depreciation and amortization 178 157 342 313 Taxes other than income taxes 90 85 1 75 162 Totaloperatingexpenses 784 688 1,537 1,330 Operatinglncome 135 121 200 183 Other Income, Net 24 24 47 47 Interest Charges 60 36 99 75 Income Before Income Taxes 99 109 148 155 Income Taxes Benefit (2) (3) (4) (5)
Netlncome 101 112 152 160 Preferred Stock Dividends I I 2 2 Net IncomeAvailable to Common Shareholder $ 100 $ 111 $ 150 $ 158 The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
8
UNION ELECTRIC COMPANY (dibla AMEREN MISSOURI)
CONSOLIDATED BALANCE SHEET (Unaudited) (In millions, except per share amounts)
June 30, December 31, 2022 2021 ASSETS Current Assets:
Cash and cash equivalents $ $
Accounts receivable trade (less allowance for doubtful accounts of $1 2 and $1 3, respectively) 201 I 90 Accounts receivable affiliates 55 44 Unbilled revenue 244 I 42 Miscellaneous accounts receivable 50 Inventories 426 419 Mark-to-market derivative assets 89 38 Current regulatory assets 232 I 27 Current collateral assets 199 66 Other current assets 23 38 Total current assets 1,519 I 135 Property, Plant, and Equipment, Net 15,635 15296 Investments and Other Assets:
Nuclear decommissioning trust fund 957 1,159 Regulatory assets 640 523 Pension and other postretirement benefits 225 208 Other assets 425 401 Total investments and other assets 2,247 2,291 TOTAL ASSETS $ -
19,401 $ 18,722 LIABILITIES AND SHAREHOLDERS EQUITY Current Liabilities:
Current maturities of long-term debt $ 55 $ 55 Short-term debt 285 I 65 Accounts and wages payable 388 631 Accounts payable affiliates 37 46 Taxes accrued I 34 34 Interest accrued 75 60 Mark-to-market derivative liabilities I 45 53 Current regulatory liabilities I 30 57 Other current liabilities I 34 116 Total current liabilities 1,383 I 217 Long-term Debt, Net 6,084 5564 Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and tax credits, net 1,901 1,852 Regulatory liabilities 3,121 3,354 Asset retirement obligations 770 753 Other deferred credits and liabilities 81 71 Total deferred credits and other liabilities 5,873 6,030 Commitments and Contingencies (Notes 2, 8, 9, and 10)
Shareholders Equity:
Common stock, $5 par value, I 50.0 shares authorized I 02.1 shares outstanding 511 511 Other paid-in capital, principally premium on common stock 2,725 2725 Preferred stock 80 80 Retained earnings 2,745 2,595 Total shareholders equity 6,061 5,911 TOTAL LIABILITIES AND SHAREHOLDERS EQUITY $ 19,401 $ 18,722 The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
9
UNION ELECTRIC COMPANY (dibla AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) (In millions)
Six Months Ended June 30, 2022 2021 Cash Flows From Operating Activities:
Net income $ 152 $ I 60 Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization 393 343 Amortization of nuclear fuel 28 20 Amortization of debt issuance costs and premium/discounts 3 3 Deferred income taxes and investment tax credits, net 19 (2)
Allowance for equity funds used during construction (10) (10)
Other 4 6 Changes in assets and liabilities:
Receivables (105) (135)
Inventories (7) (8)
Accounts and wages payable (159) (172)
Taxes accrued 81 I 67 Regulatory assets and liabilities (128) (165)
Assets, other 12 23 Liabilities, other 24 19 Pension and other postretirement benefits (8) 5 Counterparty collateral, net (118) (30)
Net cash provided by operating activities I 81 224 Cash Flows From Investing Activities:
Capital expenditures (806) (1101)
Nuclear fuel expenditures (22)
Purchases of securities nuclear decommissioning trust fund (122) (203)
Sales and maturities of securities nuclear decommissioning trust fund 114 208 Money pool advances, net 47 Other 18 Net cash used in investing activities (818) (1,053)
Cash Flows From Financing Activities:
Dividends on preferred stock (2)
Short-term debt, net I 20 lssuances of long-term debt 524 524 Capital contribution from parent I 83 Debt issuance costs (6) (4)
Net cash provided by financing activities 636 701 Net change in cash, cash equivalents, and restricted cash (1) (128)
Cash, cash equivalents, and restricted cash at beginning of year 8 145 Cash, cash equivalents, and restricted cash at end of period $ 7 $ 17 The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
10
UNION ELECTRIC COMPANY (dibla AMEREN MISSOURI)
CONSOLIDATED STATEMENT OF SHAREHOLDERS EQUITY (Unaudited) (In millions)
Three Months Ended Six Months Ended June 30, June 30, 2022 2021 2022 2021 Common Stock $ 511 $ 511 $ 511 $ 511 Other Paid-in Capital:
Beginning of period 2,725 2,631 2,725 2,518 Capital contributions from parent 70 183 Other paid-in capital, end of period 2,725 2,701 2,725 2,701 Preferred Stock 80 80 80 80 Retained Earnings:
Beginning of period 2,645 2,148 2,595 2,101 Net income 101 112 152 160 Dividends on preferred stock (1) (1) (2) (2)
Retained earnings, end of period 2,745 2,259 2,745 2,259 Total Shareholders Equity $ 6,061 $ 5,551 $ 6,061 $ 5,551 The accompanying notes as they relate to Ameren Missouri are an integral part of these consolidated financial statements.
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AMEREN ILLINOIS COMPANY (dlbla AMEREN ILLINOIS)
STATEMENT OF INCOME (Unaudited) (In millions)
Three Months Ended Six Months Ended June 30, June 30, 2022 2021 2022 2021 Operating Revenues:
Electric $ 585 $ 461 $ 1,128 $ 937 Natural gas 184 168 665 515 Total operating revenues 769 629 1,793 1452 Operating Expenses:
Purchased power 158 84 289 190 Natural gas purchased for resale 68 60 315 194 Other operations and maintenance 225 193 448 387 Depreciation and amortization 128 117 252 232 Taxes other than income taxes 35 34 88 80 Total operating expenses 614 488 1,392 1,083 Operating Income 155 141 401 369 Other Income, Net 25 16 49 30 Interest Charges 41 40 83 82 Income Before Income Taxes 139 117 367 317 Income Taxes 35 31 94 81 Net Income 104 86 273 236 Preferred Stock Dividends I I I Net Income Available to Common Shareholder $ 103 $ 86 $ 272 $ 235 The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (dibla AMEREN ILLINOIS)
BALANCE SHEET (Unaudited) (In millions)
June 30, December 31, 2022 2021 ASSETS Current Assets:
Cash and cash equivalents $ $
Accounts receivable trade (less allowance for doubtful accounts of $1 8 and $16, respectively) 302 228 Accounts receivable affiliates 9 24 Unbilledrevenue 156 159 Miscellaneous accounts receivable 16 1 Inventories 174 173 Mark-to-market derivative assets 68 28 Currentregulatoryassets 94 180 Other current assets 46 30 Total current assets 865 823 Property, Plant, and Equipment, Net 12,688 12,223 Investments and Other Assets:
Goodwill 411 411 Regulatory assets 82$ 752 Pension and other postretirement benefits 449 427 Other assets 47$ 399 Total investments and other assets 2,1 66 1989 TOTALASSETS $ 15,719 $ 15,035 LIABILITIES AND SHAREHOLDERS EQUITY Current Liabilities:
Current maturities of long-term debt $ 500 $ 400 Short-term debt I 41 103 Accounts and wages payable 42$ 361 Accounts payable affiliates II8 64 Current regulatory liabilities 111 54 Other current liabilities 277 251 Total current liabilities I ,575 I 233 Long-term Debt, Net 3,894 3,992 Deferred Credits and Other Liabilities:
Accumulated deferred income taxes and investment tax credits, net I ,626 I 558 Regulatory liabilities 2,484 2,374 Other deferred credits and liabilities 22$ 238 Total deferred credits and other liabilities 4,338 4,170 Commitments and Contingencies (Notes 2, 8, and 9)
Shareholders Equity:
Common stock, no par value, 45.0 shares authorized 25.5 shares outstanding Other paid-in capital 2,914 2,914 Preferred stock 49 49 Retained earnings 2,949 2,677 Total shareholders equity 5,912 5,640 TOTAL LIABILITIES AND SHAREHOLDERS EQUITY $ 15,719 $ 15,035 The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (dibla AMEREN ILLINOIS)
STATEMENT OF CASH FLOWS (Unaudited) (In millions)
Six Months Ended June 30, 2022 2021 Cash Flows From Operating Activities:
Net income $ 273 $ 236 Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization 251 231 Amortization of debt issuance costs and premium/discounts 6 6 Deferred income taxes and investment tax credits, net 55 84 Allowance for equity funds used during construction (9) (6)
Other 6 5 Changes in assets and liabilities:
Receivables (76) 43 Inventories (1) 3 Accounts and wages payable 76 (23)
Taxes accrued 62 36 Regulatory assets and liabilities 55 (273)
Assets, other (66) (46)
Liabilities, other 61 Pension and other postretirement benefits (1 8) (8)
Net cash provided by operating activities 675 286 Cash Flows From Investing Activities:
Capital expenditures (699) (646)
Money pool advances, net (20)
Other (2)
Net cash used in investing activities (699) (668)
Cash Flows From Financing Activities:
Dividends on preferred stock (1)
Short-term debt, net 38 Money pool borrowings, net (19)
Issuances of long-term debt 449 Capital contributions from parent 70 Redemption of preferred stock Debt issuance costs (5)
Other (4)
Net cash provided by financing activities 37 477 Net change in cash, cash equivalents, and restricted cash 13 95 Cash, cash equivalents and restricted cash at beginning ofyear 133 147 Cash, cash equivalents, and restricted cash at end of period $ 146 $ 242 The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements.
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AMEREN ILLINOIS COMPANY (dibla AMEREN ILLINOIS)
STATEMENT OF SHAREHOLDERS EQUITY (Unaudited) (In millions)
Three Months Ended Six Months Ended June30. June 30, 2022 2021 2022 2021 Common Stock $ $ $ $
Other Paid-in Capital:
Beginning of period 2,914 2,692 2,914 2,652 Capital contributions from parent 30 70 Other paid-in capital, end of period 2,914 2,722 2914 2,722 Preferred Stock:
Beginning of period 49 49 49 62 Redemptions of preferred stock (13)
Preferred stock, end of period 49 49 49 49 Retained Earnings:
Beginning of period 2,846 2,401 2,677 2,252 Net income 104 86 273 236 Dividends on preferred stock - (11 Retained earnings, end of period 2,949 2,487 2,949 2,487 Total Shareholders Equity $ 5,912 $ 5,258 $ 5,912 $ 5,258 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 (dlbla Ameren Missouri)
AMEREN ILLINOIS COMPANY (dlb!a Ameren Illinois)
COMBINED NOTES TO FINANCIAL STATEMENTS (Unaudited)
June 30, 2022 NOTE I
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. Amerens subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Amerens common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Amerens principal subsidiaries are listed below. Ameren has other subsidiaries that conduct other activities, such as providing shared services.
I 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 MISC.
The COVID-J 9 pandemic continues to affect our results of operations, financial position, and liquidity. While our electric sales volumes, excluding the estimated effects of weather and customer energy-efficiency programs, increased in the first six months of 2022, compared to the same period in 2021 they were comparable to pre-pandemic levels at Ameren Missouri and remain below pre-pandemic levels at Ameren Illinois. However, revenues from Ameren Illinois electric distribution business, residential and small nonresidential customers ofAmeren Illinois natural gas distribution business, and Ameren Illinois and ATXIs electric transmission businesses are decoupled from changes in sales volumes. Earnings at Ameren Missouri and those associated with Ameren Illinois large nonresidential natural gas customers are exposed to such changes. There has also been a shift in sales volumes by customer class at both Ameren Missouri and Ameren Illinois, which began in 2020, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect ofthe COVID-19 pandemic on our results of operations, financial position, and liquidity in subsequent periods will depend on its severity and longevity, future regulatory or legislative actions with respect thereto, and the resulting impact on business, economic, and capital market conditions.
Amerens and Ameren Missouris 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 Missouris subsidiaries were created for the ownership of renewable generation projects. Ameren Illinois has no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.
Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. The results of operations for an interim period may not give a true indication of results that may be expected for a full year. These financial statements should be read in conjunction with the financial statements and accompanng notes included in the Form 10-K.
Variable Interest Entities As of June 30, 2022, and December 31 2021 Ameren had unconsolidated variable interests as a limited partner in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $61 million and $56 million, respectively, included in Other assets on Amerens consolidated balance sheet. Any earnings or losses related to these investments are included in Other Income, Net on Amerens consolidated statement of income and comprehensive income. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of June 30, 2022, the maximum exposure to loss related to these variable interests is limited to the investment in these partnerships of $61 million plus associated outstanding funding commitments of $22 million.
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Company-owned Life Insurance Ameren and Ameren Illinois have company-owned life insurance, which is recorded at the net cash surrender value. The net cash surrender value is the amount that can be realized under the insurance policies at the balance sheet date. As of June 30, 2022, the cash surrender value of company-owned life insurance atAmeren and Ameren Illinois was $244 million (December 31 2021 $278 million) and $115 million (December 31 2021 $117 million), respectively, while total borrowings against the policies were $108 million (December 31 2021 $109 million) at both Ameren and Ameren Illinois. Ameren and Ameren Illinois have the right to offset the borrowings against the cash surrender value of the policies and, consequently, present the net asset in Other assets on their respective balance sheets. The net cash surrender value of Amerens company-owned life insurance is affected by the investment performance of a separate account in which Ameren holds a beneficial interest.
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, ofthe Form 10-K for additional information and a summary of our regulatory frameworks. We are unable to predict the ultimate outcome of these matters, the timing of final decisions of the various agencies and courts, or the impact on our results of operations, financial position, or liquidity.
Missouri 2022 Electric Service Regulatory Rate Review In August 2022, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by
$316 million. The electric rate increase request is based on a 10.2% ROE, a capital structure composed of5l.9% common equity, a rate base of
$1 I .6 billion, and a test year ended March 31 2022, with certain pro-forma adjustments expected through an anticipated true-up date of December 31 2022. Ameren Missouri also requested the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable energy standard costs that the MoPSC previously authorized in earlier electric rate orders, as well as the use of an electric property tax tracker allowed under Missouri Senate Bill 745 discussed below. The electric rate increase request reflects the following:
. increased infrastructure investments made underAmeren Missouris Smart Energy Plan, including increased cost olcapital and depreciation expense;
. increased net fuel expense due to reduced off system sales, primarily driven by expected reduced operations at the Rush Island Energy Center; and
. extending the retirement date of the Sioux Energy Center from 2028 to 2030, consistent with Ameren Missouris 2022 Change to the 2020 IRP, in order to ensure reliability during the transition to clean energy generation.
In connection with the planned accelerated retirement ofthe Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute. As such, Ameren Missouri did not request a change in the depreciation rates related to the Rush Island Energy Center in this electric service regulatory rate review.
The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 1 1 months, with a decision by the MoPSC expected by June 2023 and new rates effective by July 2023. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient forAmeren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.
Missouri Senate Bill 745 In June 2022, Missouri Senate Bill 745 was enacted and will become effective on August 28, 2022. The law extended Ameren Missouris PISA election through December 2028 and allows for an additional five-year extension through December 2033 if requested by Ameren Missouri and approved by the MoPSC, among other things. The law established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1 2024, and will be based on the revenue requirement established in the immediately preceding rate order. The current rate limitation, which is effective through 2023, is a 285% 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 201 7, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 201 8 MoPSC order. The law also established electric and natural gas property tax trackers that allow Ameren Missouri to defer the difference between actual property taxes 17
incurred and related taxes included in customer rates as a regulatory asset or regulatory liability, with the difference expected to be reflected in rate base in a subsequent rate order.
Solar Generation Facilities In February 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 150-MW solar generation facility, which is expected to be located in southeastern Illinois and, if approved by the MoPSC, serve customers under Ameren Missouris Renewable Solutions Program discussed below. In June 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 200-MW solar generation facility, which is expected to be located in central Missouri and support Ameren Missouris compliance with the state of Missouris requirement of achieving 1 5% of retail sales from renewable energy sources, of which 2% must be derived from solar energy sources. The acquisitions are aligned with the 2022 Change to the 2020 IRP, which Ameren Missouri filed with the MoPSC in June 2022, and are subject to certain conditions, including the issuance of certificates of convenience and necessity by the MoPSC, obtaining MISO transmission interconnection agreements, and approval by the FERC. In July 2022, Ameren Missouri filed for certificates of convenience and necessity with the MoPSC for both facilities and expects decisions by March 2023 and April 2023 for the 200-MW facility and the 150-MW facility, respectively. Depending on the timing of regulatory approvals and the impact of potential sourcing issues resulting from a Department of Commerce investigation of solar panels imported from four Southeast Asian countries initiated in late March 2022 and the detention of certain solar panels sourced from China as a result of the Uyghur Forced Labor Prevention Act that was passed in December 2021 the projects could be completed as early as the fourth quarter of 2024.
Renewable Solutions Program In July 2022, Ameren Missouri filed a request with the MoPSC seeking approval of its Renewable Solutions Program and a tariff related to participation in the program. The program would allow certain commercial, industrial, and governmental customers to receive up to I 00% of their energy from renewable resources. Based on customer contracts, the program would enable Ameren Missouri to supply renewable solar energy generated by the 150-MW facility discussed above to customers that enroll in the program.
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 Missouris planned accelerated retirement of the Rush Island Energy Center as a result ofthe NSR and Clean Air Act Litigation discussed in Note 9 Commitments and Contingencies. The MoPSC staffs review includes potential impacts on the reliability and cost ofAmeren Missouris service to its customers; Ameren Missouris plans to mitigate the customer impacts ofthe accelerated retirement; and the prudence ofAmeren Missouris actions and decisions with regard to the Rush Island Energy Center, which is expected to be addressed in the current electric service regulatory rate review, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement of the Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. Ameren Missouri is unable to predict the results of this matter. Results ofthe review could be used in other MoPSC proceedings, which could have a material adverse effect on the results of operations, financial position, and liquidity ofAmeren and Ameren Missouri.
December 2021 MoPSC Electric and Natural Gas Rate Orders In December 2021 the MoPSC issued orders in Ameren Missouris 2021 electric service and natural gas delivery service regulatory rate reviews. The new electric and natural gas rates approved by these orders went into effect on February 28, 2022.
Illinois MYRP ROE Perfonnance Metrics Under an MYR the ROE approved by the ICC would be subject to annual adjustments during the four-year period based on certain performance metrics, with aggregate symmetrical performance-based ROE incentives and penalties ranging from 20 to 60 basis points annually.
In January 2022, Ameren Illinois filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties. In April 2022, Ameren Illinois filed a revised request proposing total ROE incentives and penalties of 24 basis points, allocated evenly among eight proposed performance metrics. In May 2022, the ICC staff recommended that the ICC allow ROE incentives and penalties of no less than 20 basis points and no more than 24 basis points, allocated evenly across the number of performance metrics ultimately approved by the ICC. The ICC is required to issue an order on this matter by September 30, 2022.
Electric Distribution Service Rates Under IEIMA In April 2022, Ameren Illinois filed its annual electric distribution service performance-based formula rate update with the ICC to be used for 2023 rates. In July 2022, Ameren Illinois filed a revised request seeking to increase its annual revenues for electric distribution service by $84 million. The updated request reflects an increase to the annual performance-based formula rate based on 2021 actual recoverable costs 18
and expected net plant additions for 2022, an increase to include the 2021 revenue requirement reconciliation adjustment including a capital structure composed of 54% common equity, and a decrease for the conclusion of the 2020 revenue requirement reconciliation adjustment, which will be fully collected from customers in 2022, consistent with the ICCs December 2021 annual update filing order. In June 2022, the ICC staff submitted its calculation of the revenue requirement included in Ameren Illinois update filing, recommending a $60 million increase in Ameren Illinois electric distribution service rates, which is based on a capital structure composed of 50% common equity. An ICC decision in this proceeding is required by December 2022, with new rates effective in January 2023.
Electric Customer Energy-Efficiency Investments In June 2022, Ameren Illinois filed its annual electric customer energy-efficiency formula rate update to increase its rates by $17 million with the ICC. An ICC decision in this proceeding is required by December 2022, with new rates effective January 2023.
In June 2022, the ICC issued an order approving Ameren Illinois revised energy-efficiency plan that includes annual investments in electric energy-efficiency programs of approximately $1 20 million per year through 2025, which reflects the increased level of annual investments allowed under the IETL. The ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future plan program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs. The electric energy-efficiency program investments and the return on those investments are collected from customers through a rider and are not recovered through the electric distribution service performance-based formula ratemaking framework.
Illinois Senate Bill 3866 In May 2022, Illinois Senate Bill 3866 was enacted and became effective. This legislation makes certain amendments to the IETL, including amendments to increase the level of funding for the Energy Transition Assistance Fund. As a result of this legislation, Ameren Illinois expects to collect up to $50 million annually related to this fund, beginning in January 2023. Funds collected by Ameren Illinois will be remitted in the month following collection to an Illinois state agency, with no impact to results of operations.
RTO Cost Benefit Study In July 2022, an Illinois law prohibiting the states oversight of certain electric utilities choice of RTO membership ceased to be effective.
Given the change in law and the high prices resulting from MISOs 2022 capacity auction, the ICC issued an order requiring Ameren Illinois to perform a cost benefit study ofcontinued participation in the MISO compared to participation in PJM Interconnection LLC, another RTO. The cost benefit study will examine the impacts of participation in each RTO, including reliability, resiliency, affordability, and environmental impacts, among other things, for a period of five to I 0 years beginning June 2024. The ICC order requires Ameren Illinois to file the study by July 2023. A 30-day comment period will follow. The ICC is under no obligation to issue an order in this matter.
QIP Reconciliation Hearing In March 2020, Ameren Illinois filed its annual request with the ICC for a reconciliation hearing to determine the accuracy and prudence of natural gas capital investments recovered under the QIP rider during 201 9. In August 2021 the Illinois Attorney Generals office challenged the recovery of capital investments that were made during 201 9, alleging that the ICC should disallow approximately $70 million in natural gas capital investments as improper and imprudent, providing a potential over-recovery of approximately $3 million in 201 9. In August and December 2021 the ICC staff filed testimony that supports the prudence and reasonableness of the capital investments made during 2019. Ameren Illinois 201 9 QIP rate recovery request under review by the ICC is within the rate increase limitations allowed by law. The ICC is under no deadline to issue an order in this proceeding.
Federal Transmission Fonnula Rate Revisions In February 2020, the MISO, on behalf ofAmeren Missouri, Ameren Illinois, and ATXI, filed requests with the FERC to revise each compans transmission formula rate calculations with respect to the calculation used for materials and supplies inventories included in rate base. In May 2020, the FERC issued orders approving the revisions prospectively. In addition, the FERC declined to order refunds for earlier periods, as requested by intervenors in Ameren Illinois filing, but directed its audit staff to review historical rate recovery in connection with an ongoing FERC audit. Separately, in March 2021 the FERC issued an order related to an intervenor challenge to Ameren Illinois 2020 transmission formula rate update. As a result of this order, in March 2021 Ameren Illinois recorded a regulatory liability of $9 million, largely as a reduction of electric operating revenues, to reflect expected refunds, including interest, primarily related to the historical rate recovery of materials and supplies inventories included in rate base. The refund amount was reflected in rates as of January 2022 and will be refunded to customers by the end of 2022. Ameren Missouri, Ameren Illinois, and ATXI filed appeals of the FERCs May 2020 and March 2021 orders, and related FERC orders denying requests for rehearing, to the United States Court ofAppeals for the District of Columbia Circuit. In January 2022, the appeals were consolidated by the court. The court is under no deadline to address the appeal. Regardless of the outcome of the 19
appeal, the impact ofthe May 2020 and March 2021 orders is not expected to be material toAmerens, Ameren Missouris, orAmeren Illinois results of operations, financial position, or liquidity.
FERC Complaint Cases Since November 2013, the allowed base ROE for FERC-regulated transmission rate base under the MlSO 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, forthe periods November 2013 to February 2015 and from late September 2016 forward. In June 2020, various parties filed requests for rehearing with the FERC, challenging the new ROE methodology established by the May 2020 order. In July 2020, the FERC denied the rehearing requests without addressing the issues raised, and indicated it will address the requests for rehearing in a future order. Also in July 2020, Ameren Missouri, Ameren Illinois, and AIXI filed an appeal of the May 2020 order to the United States Court ofAppeals for the District of Columbia Circuit, challenging the refunds required for the period from September 2016 to May 2020.
The court is under no deadline to address the appeal.
Ameren and Ameren Illinois have paid the refunds, including interest, associated with the allowed base ROE set by the May 2020 order.
NOTE 3 SHORT-TERM DEBT AND LIQUIDITY The liquidity needs ofthe Ameren Companies are typically supported through the use of available cash, drawings under committed credit agreements, commercial paper issuances, and, in the case ofAmeren 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 CreditAgreement and the Illinois CreditAgreement are available to support issuances underAmeren (parent)s, Ameren Missouris, and Ameren Illinois commercial paper programs, respectively, subject to borrowing sublimits, and the issuance of letters of credit. As of June 30, 2022, based on commercial paper outstanding and letters of credit issued under the Credit Agreements, along with cash and cash equivalents, the net liquidity available to Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively, was $1 .3 billion. The Ameren Companies were in compliance with the covenants in their CreditAgreements as of June 30, 2022. As of June 30, 2022, the ratios of consolidated indebtedness to consolidated total capitalization, calculated in accordance with the provisions of the Credit Agreements, were 59%,
51%, and 44% forAmeren, Ameren Missouri, and Ameren Illinois, respectively.
The following table presents commercial paper outstanding, net of issuance discounts, as of June 30, 2022, and December 31 2021 There , .
were no borrowings outstanding under the Credit Agreements as of June 30, 2022, or December 31 2021. ,
June 30, 2022 December 31, 2021 Ameren (parent) $ 595 $ 277 Ameren Missouri 285 165 Ameten Illinois 141 103 Ameren consolidated $ 1,021 $ 545 The following table summarizes the activity and relevant interest rates for Ameren (parent)s, Ameren Missouris, and Ameren Illinois commercial paper issuances and borrowings under the Credit Agreements in the aggregate for the six months ended June 30, 2022 and 2021:
Ameren Ameren Ameren Ameren (parent) Missouri Illinois Consolidated 2022 Average daily amount outstanding $ 374 $ 271 $ 57 $ 702 Weighted-average interest rate 0.87 % 0.65 % 0.47 % 0.75 %
Peak amount outstanding during period(a) $ 595 $ 539 $ 142 $ 1,101 Peakinterest rate 2.05 % 2.05 % 2.05 % 2.05 %
2021 Average daily amount outstanding $ 388 $ 183 $ 211 $ 782 Weighted-averageinterestrate 0.24% 0.22% 0.22% 0.23%
Peak amount outstanding during periodt2) $ 650 $ 546 $ 485 $ I 134 Peak interest rate 0.33 % 0.25 % 0.25 % 0.33 %
(a) The timing of peak outstanding commercial paper issuances and borrowings under the Credit Agreements varies by company. Therefore, the sum of individual company peak amounts may not equal theAmeren consolidated peakforthe period.
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Money Pools Ameren has money pool agreements with and among its subsidiaries to coordinate and provide for certain short-term cash and working capital requirements. The average interest rate for borrowings under the utility money pool for the three and six months ended June 30, 2022, was 0.98% and 0.69%, respectively (2021 0.22% and 0.22%, 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 June 30, 2022 and 2021.
NOTE 4 - LONG-TERM DEBT AND EQUITY FINANCINGS Ameren For the three and six months ended June 30, 2022, Ameren issued a total of 0.2 million and 0.3 million shares of common stock, respectively, under its DRPIus and 401(k) plan, and received proceeds of $4 million and $1 7 million, respectively, and had a receivable of $8 million as of June 30, 2022. In addition, in the first quarter of 2022, Ameren issued 0.4 million shares of common stock valued at $31 million upon the settlement of stock-based compensation awards.
In May 2021 Ameren entered into an equity distribution sales agreement pursuant to which Ameren may offer and sell from time to time up to
$750 million of its common stock through an ATM program, which includes the ability to enter into forward sales agreements. There were no shares issued under the ATM program for the three and six months ended June 30, 2022. As of June 30, 2022, Ameren had approximately
$90 million of common stock available under the ATM program, which takes into account the forward sale agreements in effect as of June 30, 2022, discussed below.
Ameren has entered into multiple forward sale agreements, including the July 2022 forward sale agreement discussed below, under the ATM program with various counterparties relating to 5.8 million shares of common stock. Ameren expects to settle approximately $300 million of the forward sale agreements by December 31 2022. ,
Related to the forward sale agreements outstanding as of June 30, 2022, these agreements can be settled at Amerens discretion on or prior to dates ranging from May 3, 2023 to February 22, 2024. On a settlement date or dates, ifAmeren elects to physically settle the forward sale agreement, Ameren will issue shares of common stock to the counterparties at the then-applicable forward sale price. The initial forward sale price for the agreements ranged from $86.35 to $94.80 with an average initial forward sale price of $89.78. Each initial forward sale price is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75 basis points, and will be subject to decrease on certain dates specified in the forward sale agreements by specified amounts related to expected dividends on shares of the common stock during the term of the forward sale agreements. If the overnight bank funding rate is less than the spread on any day, the interest rate factor will result in a reduction of the forward sale price. The forward sale agreements will be physically settled unless Ameren elects to settle in cash or to net share settle. At June 30, 2022, Ameren could have settled the forward sale agreements with physical delivery of 5.6 million shares of common stock to the respective counterparties in exchange for cash of $500 million. Alternatively, the forward sale agreements could have also been settled at June 30, 2022, with delivery of approximately $8 million of cash or approximately 0.1 million shares of common stock to the counterparties. In connection to the forward sale agreements, the various counterparties, or their affiliates, borrowed from third parties and sold 5.6 million shares of common stock. The gross sales price of these shares totaled $51 0 million. In connection with such sales, the counterparties were deemed to have received commissions of $5 million. Ameren has not received any proceeds from such sales of borrowed shares. The forward sale agreements have been classified as equity transactions.
In July 2022, Ameren entered into a forward sale agreement under the ATM program relating to 0.2 million shares of common stock. The July 2022 forward sale agreement can be settled at Amerens discretion on or prior to March 8, 2024. The initial forward sale price was $90.77 for the July 2022 forward sale agreement.
Ameren Missouri In April 2022, Ameren Missouri issued $525 million of 3.90% first mortgage bonds due April 2052, with interest payable semiannually on April 1 and October 1 of each year, beginning October 1 2022. Ameren Missouri received net proceeds of $51 9 million, which were used to repay short-term debt and for near-term capital expenditures. Ameren Missouri intends to allocate an amount equal to the net proceeds to sustainability projects meeting certain eligibility criteria.
ATXI In November 2021 pursuant to a note purchase agreement, ATXI agreed to issue $95 million of its 2.96% senior unsecured notes due 2052, with interest payable semiannually on February 25 and August 25 of each year, beginning February 25, 2023, through a private placement offering exempt from registration under the Securities Act of I 933, as amended. ATXI expects to issue the notes and receive net proceeds of
$95 million in August 2022, which will be used to refinance the remaining portion of an intercompany long-term note with Ameren 21
(parent), repay a $50 million principal payment of its 3.43% senior unsecured notes, and to repay short-term debt.
Indenture Provisions and Other Covenants See Note 5 Long-term Debt and Equity Financings under Part II, Item 8, 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 June 30, 2022, the Ameren Companies were in compliance with the provisions and covenants contained in their indentures and articles of incorporation, as applicable, and AIXI was in compliance with the provisions and covenants contained in its note purchase agreements.
Off-balance-sheet Arrangements At June 30, 2022, none of the Ameren Companies had any significant off-balance-sheet financing arrangements, other than variable interest entities and the multiple forward sale agreements under the ATM program relating to common stock. See Note I Summary of Significant Accounting Policies for further detail concerning variable interest entities.
NOTE 5 OTHER INCOME, NET The following table presents the components of Other Income, Net in the Ameren Companies statements of income for the three and six months ended June 30, 2022 and 2021:
Three Months Six Months 2022 2021 2022 2021 Ameren:
Allowanceforequityfundsusedducingconstruction $ 11 $ 9 $ 19 $ 16 Interest income on industrial development revenue bonds 6 6 12 12 Non-service cost components of net periodic benefit income(8) 47 34 93 68 Miscellaneousincome 6 7 13 12 Donations (2) (1) (4) (4)
Miscellaneous expense (6) (6) (11) (9)
Total Other Income, Net $ 62 S 49 $ 122 $ 95 Ameren Missouri:
Allowanceforequityfundsusedduringconstruction $ 6 $ 6 $ 10 $ 10 Interest income on industrial development revenue bonds 6 6 12 12 Non-service cost components of net periodic benefit income(8) j4 14 28 28 Miscellaneous income I 3 1 Donations (1) (1) (2) (1)
Miscellaneous expense (2) (1) (4) (3)
Total Other Income, Net $ 24 $ 24 $ 47 $ 47 Ameren Illinois:
Allowance for equity funds used during construction $ 5 $ 3 $ 9 $ 6 Non-service cost components of net periodic benefit income 21 14 42 28 Miscellaneousincome 3 3 5 4 Donations (1) (2) (3)
Miscellaneous expense (3) (4) (5) (5)
TotalOtherincomeNet $ 25 $ 16 $ 49 $ 30 (a) For the three and six months ended June 30, 2022, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $5 million and $11 million, respectively, due to a regulatory tracking mechanism for the difference between the level of such costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. The deferral was $(3) million for both the three and six months ended June 30, 2021. See Note 11 Retirement Benefits for additional information.
NOTE 6 DERIVATIVE FINANCIAL INSTRUMENTS We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following:
. an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices;
. market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory;
. actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays; and
. actual off-system sales revenues that differ from anticipated revenues.
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The derivatives that we use to hedge these risks are governed by our risk management policies for forward contracts, futures, options, and swaps. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. The goal of the hedging program is generally to mitigate financial risks while ensuring that sufficient volumes are available to meet our requirements. Contracts we enter into as part of our risk management program may be settled financially, settled by physical delivery, or net settled with the counterparty.
All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. Many of our physical contracts, such as our purchased power contracts, qualify for the NPNS exception to derivative accounting rules. The revenue or expense on NPNS contracts is recognized at the contract price upon physical delivery. The following disclosures exclude NPNS contracts and other non-derivative commodity contracts that are accounted for under the accrual method of accounting.
If we determine that a contract meets the definition of a derivative and is not eligible for the NPNS exception, we review the contract to determine whether the resulting gains or losses qualify for regulatory deferral. Derivative contracts that qualify for regulatory deferral are recorded at fair value, with changes in fair value recorded as regulatory assets or liabilities in the period in which the change occurs. We believe derivative losses and gains deferred as regulatory assets and liabilities are probable of recovery, or refund, through future rates charged to customers. Regulatory assets and liabilities are amortized to operating income as related losses and gains are reflected in rates charged to customers. Therefore, gains and losses on these derivatives have no effect on operating income. As of June 30, 2022, and December 31 2021, ,
all contracts that met the definition of a derivative and were not eligible for the NPNS exception received regulatory deferral. Cash flows for all derivative financial instruments are classified in cash flows from operating activities.
The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of June 30, 2022, and December 31 2021 As of June 30, 2022, these contracts extended through October 2024, October 2027, May 2032 and March 2024 for fuel oils, natural gas, power and uranium, respectively.
Quantity (in millions)
June30 2022 December31 2021 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons) 21 21 30 30 Naturalgas(inmmbtu) 44 152 196 35 144 179 Power (in MWhs) 3 6 9 6 6 12 Uranium (pounds in thousands) 496 496 586 586 The following table presents the carrng value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of June 30, 2022, and December 31 2021: ,
June 30, 2022 December 31, 2021 Ameren Ameren Ameren Ameren Balance Sheet Location Missouri Illinois Ameren Missouri Illinois Ameren Fuel oils Mark-to-market derivative assets $ 22 $ $ 22 $ 8 $ $ 8 Other assets B 8 5 5 Natural gas Mark-to-market derivative assets 14 59 73 7 28 35 Other assets 14 27 41 5 13 18 Power Mark-to-market derivative assets 50 9 59 23 23 Other assets I I Uranium Mark-to-market derivative assets 3 3 Otherassets I I I 1 Totalassets $ 112 $ 96 $ 20$ $ 49 $ 41 $ 90 Natural gas Mark-to-market derivative liabilities 4 (a) (a) 2 (a) (a)
Other current liabilities 7 11 6 8 Other deferred credits and liabilities 2 4 6 1 2 3 Power Mark-to-market derivative liabilities 141 (a) (a) 50 (a) (a)
Other current liabilities I 142 9 59 Otherdeferred credits and liabilities 24 53 77 23 108 131 Uranium Mark-to-market derivative liabilities (a) (a) I (a) (a)
Other current liabilities I Total liabilities $ 171 $ 65 $ 236 $ 77 $ 125 $ 202 (a) Balance sheet line item not applicable to registrant.
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We believe that entering into master netting arrangements or similar agreements mitigates the level of financial loss that could result from default by allowing net settlement of derivative assets and liabilities. These master netting arrangements allow the counterparties to net settle sale and purchase transactions. Further, collateral requirements are calculated at the master netting arrangement or similar agreement level by counterparty.
The following table provides the recognized gross derivative balances and the net amounts of those derivatives subject to an enforceable master netting arrangement or similar agreement as of June 30, 2022, and December 31 2021: ,
Gross Amounts Not Offset in the Balance Sheet Gross Amounts Recognized in the cash collatel Net Commodity Contracts Eligible to be Offset Balance Sheet Derivative Instruments ReceivedlPostedfa) Amount June 30, 2022 Assets:
Ameren Missouri $ 112 $ 36 $ 15 $ 61 Ameren Ilhnois 96 16 15 65 Ameren $ 208 $ 52 $ 30 $ 126 Liabilities:
Ameren Missouri $ 171 $ 36 $ 127 $ 8 Amecen Illinois 65 16 49 Ameren $ 236 $ 52 $ 127 $ 57 December31, 2021 Assets:
AmerenMissoun $ 49 $ 15 $ $ 34 Ameren Illinois 41 4 37 Ameren $ 90 $ 19 $ $ 71 Liabilities:
AmerenMissoun $ 77 $ 15 $ 47 $ 15 Amerenlilinois 125 4 121 Ameren $ 202 $ 19 $ 47 $ 136 (a) Cash collateral received reduces gross asset balances and is included in Other current liabilities and Other deferred credits and liabilities on the balance sheet. Cash collateral posted reduces gross liability balances and is included in Other current assets and Other assets on the balance sheet.
Credit Risk In determining our concentrations of credit risk related to derivative instruments, we review our individual counterparties and categorize each counterparty into groupings according to the primary business in which each engages. As of June 30, 2022, if counterparty groups were to fail completely to perform on contracts, Ameren, Ameren Missouri, and Ameren Illinois maximum exposure related to derivative assets, predominantly from financial institutions, was $1 72 million, $83 million, and $89 million, respectively. The potential loss on counterparty exposures may be reduced or eliminated by the application of master netting arrangements or similar agreements and collateral held. As of June 30, 2022, the potential loss after consideration of the application of master netting arrangements or similar agreements and collateral held forAmeren, Ameren Missouri, and Ameren Illinois was $108 million, $42 million, and $66 million, respectively.
Certain of our derivative instruments contain collateral provisions tied to the Ameren Companies credit ratings. If our credit ratings were downgraded below investment grade, or if a counterparty with reasonable grounds for uncertainty regarding our ability to satisfy an obligation requested adequate assurance of performance, additional collateral postings might be required. The additional collateral required is the net liability position allowed under master netting arrangements or similar agreements, assuming (1 ) the credit risk-related contingent features underlying these arrangements were triggered and (2) those counterparties with rights to do so requested collateral. The following table presents, as of June 30, 2022, 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 Cash Potential Aggregate Amount of Derivative Liabilitiesfa) Collateral Posted Additional Collateral Requiredt Ameren Missouri $ 76 $ 29 $ 12 Ameren Illinois 12 4 Ameren $ 88 $ 29 $ 16 (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.
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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 JO-K for information related to hierarchy levels and valuation techniques.
We consider nonperlormance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g. collateral). Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in the three and six months ended June 30, 2022 or 202J At June 30, 2022, and December 3J 202J the counterparty default risk valuation adjustment related to derivative contracts was immaterial forAmeren, Ameren Missouri, and Ameren Illinois.
The following table sets forth, by level within the fair value hierarchy, our assets and liabilities measured at fair value on a recurring basis as of June 30, 2022, and December 3J 202J: ,
June30, 2022 December3l,2021 Level I Level 2 Level 3 Total Level I Level 2 Level 3 Total Assets:
Ameren Missouri Derivative assets commodity contracts:
Fueloils $ 27 $ $ 3 $ 30 $ 13 $ $ $ 13 Naturalgas I 27 28 12 12 Power 21 29 50 10 13 23 Uranium 4 4 I I Total derivative assets commodity contracts
$ 49 $ 27 $ 36 $ 112 $ 23 $ 12 $ 14 $ 49 Nuclear decommissioning trust fund:
Equity securities:
U.S. large capitalization $ 602 $ $ $ 602 $ 824 $ $ $ 824 Debt securities:
U.S.Treasuryandagencysecurities 173 173 141 141 Corporatebonds 121 121 131 131 Other 54 54 56 56 a) (a)
Total nucleardecommissioningtrustfund $ 602 $ 348 $ $ 950 $ 824 $ 328 S $ 1,152 Total Ameren Missouri $ 651 $ 375 $ 36 $ 1,062 $ 847 $ 340 S 14 $ 1,201 Ameren Illinois Derivative assets commodity contracts:
Naturalgas $ 5 $ 71 $ 10 $ 86 $ I $ 33 $ 7 $ 41 Power 10 10 TotalAmeren Illinois $ 5 $ 71 $ 20 $ 96 $ I $ 33 $ 7$ 41 Ameren Derivative assets commodity contractstb)
$ 54 $ 9$ $ 56 $ 208 $ 24 $ 45 $ 21 $ 90 Nuclear decommissioning trustfund(c) 602 348 950 (a) 824 328 I 152 (a)
Total Ameren $ 656 $ 446 $ 56 $ 1,158 S 848 $ 373 $ 21 $ I 242 Liabilities:
Ameren Missouri Derivative liabilities commodity contracts:
Natural gas $ $ 4 $ 2 $ 6 $ $ 2 $ 1 $ 3 Power 100 65 165 45 28 73 Uranium I I TotalAmeren Missouri $ 100 $ 4 $ 67 $ 171 $ 45 $ 2 $ 30 $ 77 25
June 30, 2022 December 31, 2021 Levell LeveI2 LeveI3 Total Levell Level2 Level3 Total Ameren Illinois Derivative liabilities commodity contracts:
Naturalgas $ $ 6 $ 5 $ 11 $ $ 5 $ 3 $ 8 Power 54 54 117 117 TotalAmeren Illinois $ $ 6 $ 59 $ 65 $ $ 5 $ 120 $ 125 Ameten Derivative liabilities commodity contractstb)
$ 100 $ 10 $ 126 $ 236 $ 45 $ 7 $ 150$ 202 (a) Balance excludes $7 million of cash and cash equivalents, receivables, payables, and accrued income, net, for both June 30, 2022, and December 31 2021 ,
(b) See the Ameren Missouri and Ameren Illinois sections of the table for a breakout of the fair value ofAmerens derivative assets and liabilities by type of commodity.
(c) See the Ameren Missouri section of the table for a breakout of the fair value ofAmerens nuclear decommissioning trust fund by investment type.
Level 3 fuel oils, natural gas, and uranium derivative contract assets and liabilities measured at fair value on a recurring basis were immaterial for all periods presented. The following table presents the fair value reconciliation of Level 3 power derivative contract assets and liabilities measured at fair value on a recurring basis for the three and six months ended June 30, 2022 and 2021:
2022 2021 Ameren Ameren Ameren Ameren Missouri Illinois Ameren Missouri Illinois Ameren For the three months ended June 30:
Beginning balance atApril 1 $ (53) $ (74) $ (127) $ (3) $ (185) $ (188)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities (5) 32 27 (1) 15 14 Settlements - 22 (2) 20 (1) 4 3 Ending balance at June 30 $ (36) $ (44) $ (80) $ (5) $ (166) $ (171)
Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ 2 $ 30 $ 32 $ (2) $ 15 $ 13 For the six months ended June 30:
Beginning balance at January 1 $ (15) $ (117) $ (132) $ 2 $ (198) $ (196)
Realized and unrealized gains/(losses) included in regulatory assets/liabilities (45) 74 29 (6) 24 18 Sefflements --- ----------
U)
Ending balance at June 30 $ (36) $ (44) $ (80) $ (5) $ (166) $ (171)
Change in unrealized gains/(losses) related to assets/liabilities held at June 30 $ (36) $ 72 $ 36 $ (3) $ 24 $ 21 All gains or losses related to our Level 3 derivative commodity contracts are expected to be recovered or returned through customer rates; therefore, there is no impact to either net income or other comprehensive income resulting from changes in the fair value of these instruments.
The following table describes the valuation techniques and significant unobservable inputs utilized for the fair value of our Level 3 power derivative contract assets and liabilities as of June 30, 2022, and December 31 2021: ,
Weighted Commodity Assets Liabilities Valuation Technique(s) Unobservable Inputfa) Range Average(b) 2022 Power(C) off-peak pricing
$ 39 $ (119) Discounted cash flow 36 122 65 Nodal basis ($/MWh) (17) 3 (6)
Trend rate (%) - 3 2 2021 Power(d) $ 13 (145) Discounted cash flow AfagefOIWardpknd off-peak pricing 32 55 40 Nodal basis ($/MVVh) (14) 0 (2)
Trend rate (%) (e) 0 (a) Generally, significant increases (decreases) in these inputs in isolation would result in a significantly higher (lower) fair value measurement.
(b) Unobservable inputs were weighted by relative fair value.
(c) Valuations through 2031 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2031 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials.
(d) Valuations through 2029 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2029 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials.
(e) No meaningful range around weighted average.
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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 June 30, 2022, and December 31 2021: ,
Fair Value Carryin Amoun Level I Level 2 Level 3 Total June 30, 2022 Ameren:
Cash, cash equvaIents, and restricted cash $ 161 $ 161 $ $ $ 161 Investments in industrial development revenue bonds(a) 248 248 248 Short-term debt 1,021 1,021 1,021 Long-term debt (including current portion)(a) 13,590 fb) 12,016 500 fc] 12,516 Ameren Missouri:
Cash, cash equivalents, and restricted cash $ 7 $ 7 $ $ $ 7 Investments in industrial development revenue bonds(a) 248 248 248 Short-term debt 285 285 285 Long-term debt (including current portion)(2J 6,139 fb) 5,641 5,641 Ameren Illinois:
Cash, cash equivalents, and restricted cash $ 146 $ 146 $ $ $ 146 Short-termdebt 141 141 141 (i))
Long-term debt (including current portion) 4,394 4,037 4,037 December31, 2021 Ameren:
Cash, cash equivalents, and restricted cash $ 155 $ 155 $ $ $ 155 Investments in industrial development revenue bondsfa) 248 248 248 Short-term debt 545 545 545 Long-term debt (including current portion)(a) 13,067 (b) 13,930 591 fc) 14,521 Ameren Missouri:
Cash, cash equivalents, and restricted cash $ 8 $ 8 $ $ $ 8 Investments in industrial development revenue bondsfa) 248 248 248 Short-termdebt 165 165 165 Long-term debt (including current portion)(a) 5,619 fb) 6,321 6,321 Ameren Illinois:
Cash, cash equivalents, and restricted cash $ 133 $ 133 $ $ $ 133 Short-termdebt 103 103 103 Long-term debt (including current portion) 4,392 fb] 497J . 4,97J (a) Ameren and Ameren Missouri have investments in industrial development revenue bonds, classified as held-to-maturity and recorded in OtherAssets, that are equal to the finance obligations for the Peno Creek and Audrain CT energy centers. As of June 30, 2022, and December 31 2021 the carrying amount of both the investments in industrial development revenue bonds and the nance obligations approximated fair value.
(b) Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $97 million, $43 million, and $37 million forAmeren, Ameren Missouri, and Ameren Illinois, respectively, as of June 30, 2022. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $94 million,
$38 million, and $39 million forAmeren, Ameren Missouri, andAmeren Illinois, respectively, as of December 31, 2021.
(c) The Level 3 fair value amount consists ofATXIs senior unsecured notes.
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 Amerens subsidiaries are reported as affiliate transactions on their individual financial statements, but those transactions are eliminated in consolidation for Amerens consolidated financial statements. For a discussion of material related-party agreements and money pool arrangements, see Note I 3 Related-party Transactions and Note 4 Short-term Debt and Liquidity under Part II, Item 8, ofthe Form 10-K.
Support Services Agreements Ameren Missouri and Ameren Illinois had long-term receivables included in Other assets from Ameren Services of $80 million and
$83 million, respectively, as of June 30, 2022, and $77 million and $80 million, respectively, as of December 31 2021 related to Ameren , ,
Services allocated portion ofAmerens pension and postretirement benefit plans.
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Tax Allocation Agreement See Note I Summary ofSignificantAccounting Policies under Part II, Item 8, ofthe Form 10-K for a discussion ofthetax allocation agreement. The following table presents the affiliate balances related to income taxes forAmeren Missouri and Ameren Illinois as of June 30, 2022, and December31, 2021:
June3O,2022 J December31, 2021 Income taxes payable to parent(a)
Ameren Missouri Ameren Illinois f Ameren Missouri Ameren Illinois 82 j $ $ 8 Income taxes receivable from parent(b) 45
[ 27 18 (a) Included in Accounts payable affiliates on the balance sheet.
(b) Included in Accounts receivable affiliates on the balance sheet Effects of Related-party Transactions on the Statement of Income The following table presents the impact on Ameren Missouri and Ameren Illinois of related-party transactions for the three and six months ended June 30, 2022 and 2021:
Three Months Six Months Income Statement Ameren Ameren Ameren Ameren Agreement Line Item Missouri Illinois Missouri Illinois Ameren Missouri power supply Operating Revenues 2022 $ I $ (a) $ 5 $ (a) agreements with Ameren Illinois 2021 3 (a) 5 (a)
Ameren Missouri andAmeren Illinois Operating Revenues 2022 $ 6 $ (b) $ 12 $ (b) rent and facility services 2021 7 (b) 14 (b)
Ameren Missouri and Ameren Illinois miscellaneous Operating Revenues 2022 $ (b) $ (b) $ (b) $ I support services and other services provided to AIXI 2021 (b) 2 (b) 2 Total Operating Revenues 2022 $ 7 $ (b) $ 17 $ I 2021 10 2 19 2 Ameren Illinois power supply Purchased Power 2022 $ (a) $ I $ (a) $ 5 agreements with Ameren Missouri 2021 (a) 3 (a) 5 Ameren Missouri and Ameren Illinois Purchased Power 2022 $ (b) $ (b) $ (b) $ (b) transmission services from ATXI 2021 1 1 2 1 Total Purchased Power 2022 $ (b) $ I $ (b) $ 5 2021 1 4 2 6 Ameren Missouri and Ameren Illinois Other Operations and Maintenance 2022 $ (b) $ (b) $ (b) $ I rent and facility services 2021 (b) I (b) 2 Ameren Services support services Other Operations and Maintenance 2022 $ 33 $ 32 $ 71 $ 67 agreement 2021 34 31 69 64 Total Other Operations and 2022 $ 33 $ 32 $ 71 $ 68 Maintenance 2021 34 32 69 66 Money pool borrowings (advances) (Interest Charges)IOther Income, Net 2022 $ (b) $ (b) $ (b) $ (b) 2021 (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 I 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, ofthe Form 10-K.
See also Note I Summary of SignificantAccounting Policies, Note 2 Rate and Regulatory Matters, Note 8 Related-party Transactions, and Note 1 0 Callaway Energy Center of this report.
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Environmental Matters Our electric generation, transmission, and distribution and natural gas distribution and storage operations must comply with a variety of statutes and regulations relating to the protection of the environment and human health and safety including permitting programs implemented via federal, state, and local authorities. Such environmental laws address air emissions; discharges to water bodies; the storage, handling and disposal of hazardous substances and waste materials; siting and land use requirements; and potential ecological impacts. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing, or modified facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures. We employ dedicated personnel knowledgeable in environmental matters to oversee our business activities compliance with regulatory requirements.
Environmental regulations have a significant impact on the electric utility industry and compliance with these regulations could be costly for Ameren Missouri, which operates coal-fired power plants. Regulations under the Clean Air Act that apply to the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants.
Collectively, these regulations cover a variety of pollutants, such as 502, particulate matter, NOx, mercury, toxic metals and acid gases, and CO2 emissions from new power plants. Regulations implementing the Clean WaterAct govern both intake and discharges ofwater, and may require evaluation of the ecological and biological impact of our operations and could require modifications to water intake structures or more stringent limitations on wastewater discharges. Depending upon the scope of modifications ultimately required by state regulators, capital expenditures associated with these modifications could be significant. The management and disposal of coal ash is regulated under the Resource Conservation and Recovery Act and the CCR Rule, which require the closure of certain surface impoundments at Ameren Missouris coal-fired energy centers. 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 operations at some ofAmeren Missouris 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 Missouris wind generation facilities may be subject to operating restrictions to limit the impact on protected species.
Nighttime operating restrictions may be required during the critical biological season, which typically occurs from April through October. Seasonal nighttime curtailment began at the High Prairie Renewable Energy Center at the end of March 2022, 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 result in significant impacts on its results of operations, financial position, or liquidity.
Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $125 million to $1 75 million from 2022 through 2026 in order to comply with existing environmental regulations. Additional environmental controls beyond 2026 could be required. This estimate of capital expenditures includes ash pond closure and corrective action measures required by the CCR Rule and the effluent limitation guidelines applicable to steam electric generating units, and potential modifications to cooling water intake structures at existing power plants under Clean Water Act rules, all of which are discussed below. In addition to planned retirements of fossil fuel-fired energy centers as set forth in the 2022 Change to the 2020 IRP filed with the MoPSC in June 2022 and as noted in the NSR and Clean AirAct litigation and Illinois emissions standards discussed below, Ameren Missouris current plan for compliance with existing air emission regulations includes burning low-sulfur coal and installing new or optimizing existing air pollution control equipment. The actual amount of capital expenditures required to comply with existing environmental regulations may vary substantially from the above estimates because of uncertainty as to future permitting requirements made by state regulators and the EPA, potential revisions to regulatory obligations, and the cost of potential compliance strategies, among other things.
The following sections describe the more significant environmental laws and rules and environmental enforcement and remediation matters that affect or could affect our operations. The EPA has initiated an administrative review of several regulations and proposed amendments to regulations and guidelines, including the CSAPR, which could ultimately result in the revision of all or part of such rules.
Clean AirAct Federal and state laws, including CSAPR, regulate emissions of 502 and NO through the reduction of emissions at their source and the use and retirement of emission allowances. CSAPR is implemented through a series of phases, and the second phase became effective in 201 7. In April 2022, the EPA proposed plans for additional emission reductions from power plants in Missouri, Illinois, and other states through revisions to the CSAPR; and additional emission reduction requirements may apply in subsequent years. The EPA expects to issue a final rule in March 2023. Ameren Missouri complies with current CSAPR requirements by minimizing emissions through the use of low-sulfur coal, operation of two scrubbers at its Sioux Energy Center, and optimization of other existing air pollution control equipment. Ameren Missouri could incur additional costs to lower its emissions at one or more of its energy centers to comply with additional CSAPR requirements in future years. These additional costs for compliance are expected to be recovered from customers through the FAC or higher base rates.
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Co2 Emissions Standards In June 2022, the United States Supreme Court issued its decision in West Virginia v. EPA. The decision clarifies that there are limits on how the EPA may regulate greenhouse gases absent further direction from the United States Congress. The court concluded that emission caps that would cause generation shifting from fossil-fuel-fired power plants to renewable energy facilities would require specific congressional authorization and that such authorization had not been given under the Clean Air Act. The decision by the United States Supreme Court may affect the EPAs development of any new regulations to address CO2 emissions from coal- and natural gas-fired power plants; however, at this time, Ameren Missouri cannot predict the impact of any such regulations or the decision by the United States Supreme Court on the results of operations, financial position, and liquidity ofAmeren orAmeren Missouri.
NSR and Clean AirAct Litigation In January 201 1 the United States Department of Justice, on behalf ofthe EPA, filed a complaint against Ameren Missouri in the United States District Court for the Eastern District of Missouri alleging that in performing projects at its coal-fired Rush Island Energy Center in 2007 and 201 0, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. In January 201 7, the district court issued a liability ruling against Ameren Missouri and, in September 201 9, 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 ofAppeals for the Eighth Circuit affirmed the liability ruling and the district courts remedy order as it related to the installation of a flue gas desulfurization system at the Rush Island Energy Center, but reversed the order as it related to the installation of a dry sorbent injection system at the Labadie Energy Center. In November 2021 the court of appeals issued an order denying requests for consideration previously sought by both Ameren Missouri and the United States Department of Justice.
Based on its assessment of available legal, operational, and regulatory alternatives, Ameren Missouri filed a motion in December 2021 with ,
the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. In June 2022, Ameren Missouri supplemented its filing with the district court by proposing reduced operations, mostly operating during peak demand times and emergencies until the energy center is retired. The March 31, 2024 compliance date contained in the district courts September 2019 remedy order remains in effect unless extended by the district court. In July 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISC, and Ameren Missouri has started design and procurement activities necessary to complete the upgrades and expects to complete the upgrades by late 2025. The FERC will need to approve a system support resource agreement detailing the manner of continued operation of the Rush Island Energy Center, as well as a request from Ameren Missouri for recovery of non-energy costs under the related MISC tariff. The agreement, if approved, would have a term of 12 months.
The system support resource designation and the related agreement are subject to renewal and revision. Any difference between revenues and costs under the MISC tariff is expected to be included in the FAC. The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISC determination of the Rush Island Energy Center as a system support resource or the FERCs approval. While the district court is under no deadline to issue a ruling modifying the remedy order, a decision is expected in the near term. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review the planned accelerated retirement ofthe Rush Island Energy Center. See Note 2 Rate and Regulatory Matters for additional information.
In connection with the planned accelerated retirement ofthe Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute. As such, Ameren Missouri did not request a change in the depreciation rates related to the Rush Island Energy Center in the electric regulatory rate review filed in August 2022. See Note 2 Rate and Regulatory Mailers for additional information on the August 2022 electric regulatory rate review. As of June 30, 2022, the Rush Island Energy Center had a net plant balance of approximately $0.6 billion included in plant to be abandoned, net, within Property, Plant, and Equipment, Net and a rate base of approximately $0.5 billion. See Note I Summary of Significant Accounting Policies under Part II, Item 8, ofthe Form I 0-K for additional information regarding plant to be abandoned, net. In addition, Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the planned acceleration of the retirement of the Rush Island Energy Center from 2039, the retirement year for the facility as reflected in the 2020 IRP and reflected in depreciation rates approved by the December 2021 MoPSC electric rate order.
Ameren Missouri is unable to predict the ultimate resolution ofthis mailer; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity ofAmeren and Ameren Missouri.
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Clean WaterAct The EPAs regulations implementing Section 31 6(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 plants cooling water intake screens or entrained through the plants cooling water system. All ofAmeren Missouris 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 plants water discharge permit, which is expected to be completed by 2023 forAmeren Missouri.
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. To meet the requirements of the guidelines, Ameren Missouri installed dry ash handling systems and in 2020 completed construction ofwastewater treatment facilities at three of its four coal-fired energy centers. The Meramec Energy Center is scheduled to retire in 2022 and, as a result, does not require new wastewater and dry ash handling systems.
CCR Management The EPAs CCR Rule establishes requirements for the management and disposal of CCR from coal-fired power plants and will result in the closure of certain surface impoundments at Ameren Missouris energy centers. Ameren Missouri completed the closure of all surface impoundments at its Labadie and Rush Island energy centers in 2021 and has made significant progress by closing several surface impoundments at its Sioux and Meramec energy centers. Ameren Missouri plans to complete the closures of the remaining surface impoundments as required by the CCR Rule in 2023. In January 2022, Ameren Missouri received notice of a proposed determination by the EPA that it has rejected Ameren Missouris requests to extend the timeline for operating certain surface impoundments located at the Sioux and Meramec energy centers. Pursuant to the terms of the proposed determination, compliance with the CCR Rules requirements for closure of the surface impoundments would be required I 35 days after the EPA issues a final determination. In February 2022, Ameren Missouri filed comments with the EPA requesting additional time to construct a CCR Rule-compliant impoundment at the Sioux Energy Center and complete the closure of the surface impoundments at the Meramec Energy Center. The EPA is under no deadline to issue a final determination. If Ameren Missouri was no longer able to use the surface impoundments at the Sioux or Meramec energy centers, Ameren Missouri would not be able to operate the energy centers unless an alternative for handling the CCR material was available. Ameren Missouri will retire the Meramec Energy Center in 2022, and construction of a CCR Rule-compliant surface impoundment at the Sioux Energy Center is expected to be completed by the fall of 2022 to allow for continued operations. Ameren Missouri does not expect that this matter will have a material adverse effect on its results of operations, financial position, or liquidity.
Ameren and Ameren Missouri have AROs of $77 million recorded on their respective balance sheets as of June 30, 2022, associated with CCR storage facilities. Ameren Missouri estimates it will need to make capital expenditures of $60 million to $80 million from 2022 through 2026 to implement its CCR management compliance plan, which includes installation of groundwater monitoring equipment and groundwater treatment facilities.
Remediation The Ameren Companies are involved in a number of remediation actions to clean up sites impacted by the use or disposal of materials containing hazardous substances. Federal and state laws can require responsible parties to fund remediation regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site.
As of June 30, 2022, Ameren Illinois has remediated the majority ofthe 44 former MGP sites in Illinois and could substantially conclude remediation efforts at the remaining sites by 2023. The ICC allows Ameren Illinois to recover such remediation and related litigation costs from its electric and natural gas utility customers through environmental cost riders that are subject to annual prudence reviews by the ICC. As of June 30, 2022, Ameren Illinois estimated the remaining obligation related to these former MGP sites at $78 million to $147 million. Ameren and Ameren Illinois recorded a liability of $78 million to represent the estimated minimum obligation for these sites, as no other amount within the range was a better estimate.
The scope of the remediation activities at these former MGP sites may increase as remediation efforts continue. Considerable uncertainty remains in these estimates because many site-specific factors can influence the actual costs, including unanticipated underground structures, the degree to which groundwater is encountered, regulatory changes, local ordinances, and site accessibility. The actual costs and timing of completion may vary substantially from these estimates.
Our operations or those of our predecessor companies involve the use of, disposal of, and, in appropriate circumstances, the cleanup of substances regulated under environmental laws. We are unable to determine whether such historical practices will result in future environmental commitments or will affect our results of operations, financial position, or liquidity.
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Illinois Emission Standards The IETL established emission standards that became effective in September 2021 Ameren Missouris natural gas-fired energy centers in Illinois are subject to limits on emissions, including CO2 and NOx, equal to their unit-specific average emissions from 2018 through 2020, for any rolling twelve-month period beginning October 1 2021 through 2029. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure ofthe Venice Energy Center by 2029. The reductions could also limitthe operations ofAmeren Missouris other four natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to conditions in the IETL, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service as necessary. Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the updated scheduled retirement dates ofthe natural gas-fired energy centers located in the state of Illinois.
NOTE 10 - CALLAWAY ENERGY CENTER See Note 9 Callaway Energy Center under Part II, Item 8, of the Form I 0-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 Missouris Callaway Energy Center is reported as Nuclear decommissioning trust fund in Amerens and Ameren Missouris 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 forAmeren Missouris 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 Missouris updated cost study funding analysis. See Note 13 Supplemental Information for more information on Ameren Missouris ARCs.
Maintenance Outage See Note 9 Callaway Energy Center under Part II, Item 8, of the Form I 0-K for information regarding a maintenance outage from a non-nuclear operating issue related to the Callaway Energy Centeis generator in late December 2020 and subsequent return to service on August 4, 2021 along with the related insurance claims. In April 2022, Ameren Missouri received $22 million from NEIL related to lost sales insurance claims.
Insurance The following table presents insurance coverage at Ameren Missouris Callaway Energy Center at June 30, 2022:
Most Recent Maximum Assessments Type and Source of coverage Renewal Date Maximum coverages for Single Incidents Public liability and nuclear worker liability:
American Nuclearinsurers January 1, 2022 $ 450 $
Pool participation (a) 13,073 (a) 138 )b)
)c)
$ 13523 $ 138 Property damage:
NEIL and EMANI April 1, 2022 $ 3,200 26 (e)
Accidental outage:
NEIL April 1, 2022 $ 490 $ 7 (e)
(a) Provided through mandatory participation in an industrywide retrospective premium assessment program. The maximum coverage available is dependent on the number of United States commercial reactors participating in the program.
(b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $450 million in the event of an incident at any licensed United States commercial reactor, payable at $21 million per year.
(c) Limit of liability for each incident underthe Price-Anderson liability provisions ofthe Atomic EnergyAct of 1954, as amended. This limit is subjectto 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.
(1 Accidental outage insurance provides for lost sales in the event of a prolonged accidental outage. VekIy indemnity up to $4.5 million for 52 weeks, which commences after the first 1 2 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.
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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 201 8. Owners of a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by the Price-Anderson Act.
Losses resulting from terrorist attacks on nuclear facilities insured by NEIL are subject to industrywide aggregates, such that terrorist acts against one or more commercial nuclear power plants within a stated time period would be treated as a single event, and the owners of the nuclear power plants would share the limit of liability. NEIL policies have an aggregate limit of $3.2 billion within a 12-month period for radiation events, or $1 .8 billion for events not involving radiation contamination, resulting from terrorist attacks. The EMANI policies are not subject to industrywide aggregates in the event of terrorist attacks on nuclear facilities.
If losses from a nuclear incident at the Callaway Energy Center exceed the limits of, or are not covered by insurance, or if coverage is unavailable, Ameren Missouri is at risk for any uninsured losses. If a serious nuclear incident were to occur, it could have a material adverse effect on Amerens and Ameren Missouris results of operations, financial position, or liquidity.
NOTE 11 RETIREMENT BENEFITS The following table presents the components of the net periodic benefit cost (income) incurred for Amerens pension and postretirement benefit plans for the three and six months ended June 30, 2022 and 2021:
Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2022 2021 2022 2021 2022 2021 2022 2021 Service cost(a) $ 3j $ 34 $ 64 $ 67 $ 5 $ 6 $ 10 $ 12 Non-service cost components:
Interestcost 41 38 81 76 9 8 17 16 Expected return on plan assets (80) (74) (160) (149) (22) (20) (43) (40)
Amortization of:
Prior service benefit (1) (1) (2) (2)
Actuarial loss (gain) 6 20 12 37 (5) (2) (9) (3)
Total non-service cost componentsO) $ (33) $ (16) $ (67) $ (36) $ (19) $ (15) $ (37) $ (29)
Net periodic benefit cost fincome)(c) $ (2) $ 18 $ (3) $ 31 $ (14) $ (9) $ (27) $ (17)
(a) Service cost, net of capitalization, is reflected in Operating Expenses Other operations and maintenance on Amerens statement of income.
(b) Non-service cost components are reflected in Other Income, Net on Amerens statement of income. See Note 5 Other Income, Net, for additional information.
(c) Does not include the impact of the regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates.
Ameren Missouri and Ameren Illinois are responsible for their respective share ofAmerens pension and other postretirement costs. The following table presents the respective share of net periodic pension and other postretirement benefit costs (income) incurred for the three and six months ended June 30, 2022 and 2021:
Pension Benefits Postretirement Benefits Three Months Six Months Three Months Six Months 2022 2021 2022 2021 2022 2021 2022 2021 Ameren Missourifa) $ (1) g $ (2) $ 15 $ (4) $ (1) $ (7) $ (2)
Ameren Illinois 9 1 17 (10) (8) (20) (15)
Other (1) (2) (1)
Amerenfa) $ (2) S 18 $(3) $ 31 $ (14) $ (9) $ (27) S (17)
(a) Does not include the impact ofthe regulatory tracking mechanism forthe difference between the level of pension and postretirement benefit costs incurred byAmeren 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 June 30, 2022 and 2021:
Ameren Ameren Missouri Ameren Illinois 2022 2021 2022 2021 2022 2021 Three Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 % 21 % 21 %
Increases (decreases) from:
Amortization ofdeferred investmenttax credit (1) (1)
Amortization ofexcess deferred taxesfa) (8) (9) (15) (17) (2) (2)
Depreciation differences I (1) 1 Other I Renewable and other tax creditstb) (4) (4) (10) (1 0) (1)
Statetax 5 5 3 3 7 7 Effective income tax rate 15 % 13 I (2)% (3)! 25 % 26 0/
Six Months Federal statutory corporate income tax rate 21 % 21 % 21 % 21 3/4 21 % 21 %
Increases (decreases) from:
Amortization ofdeferred investmenttax credit (1) (1)
Amortization ofexcess deferred taxes(a) (8) (9) (16) (17) (2) (3)
Depreciation differences I Renewable and othertax creditsfb) (5) (5) (10) (10)
Statetax 5 5 3 3 7 7 Effective income tax rate 13 % 12 % (3)% (3)% 26 % 25 3/4 (a) Reflects the amortization of amounts resulting from the revaluation of deferred income taxes subject to regulatory ratemaking, which are being refunded to customers. Deferred income taxes are revalued when federal or state income tax rates change, and the offset to the revaluation of deferred income taxes subject to regulatory ratemaking is recorded to a regulatory asset or liability.
(b) Includes credits associated with the High Prairie and Atchison renewable energy centers. Ameren Missouri placed the High Prairie Renewable Energy Center in service in December 2020. Additionally, Ameren Missouri placed in service the wind turbines at its Atchison Renewable Energy Center throughout the first half of 2021. The benefit of the credits associated with Missouri renewable energy standard compliance is refunded to customers through the RESRAM.
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 June 30, 2022, and December 31 2021: ,
June 30, 2022 December 31, 2021 Ameren Ameren Ameren Ameren Ameren Missouri Illinois Ameren Missouri Illinois Cash and cash equivalents $ 7 $ $ $ 8 $ $
Restricted cash included in Other current assets 7 2 4 16 4 6 Restricted cash included in Other assets 142 142 127 127 Restricted cash included in Nuclear decommissioning trust fund 5 5 4 4 Total cash, cash equivalents, and restricted cash $ 161 $ 7 $ 146 $ 155 $ 8 $ 133 Restricted cash included in Other current assets primarily represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees. Restricted cash included in ctOther assets on Amerens 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 Amerens and Ameren Illinois balance sheets include certain receivables purchased at a discount from alternative retail electric suppliers that elect to participate in the utility consolidated billing program. At June 30, 2022, and December 31 2021, ,
Other current liabilities on Amerens and Ameren Illinois balance sheets included payables for purchased receivables of $32 million and $27 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 June 30, 2022 and 2021:
Three Months Six Months 2022 2021 2022 2021 Ameren:
Beginning of period $ 28 $ 47 $ 29 $ 50 Baddebtexpense 7 (3) 11 1 Net write-offs (5) (2) (10) (9)
End of period $ 30 $ 42 $ 30 $ 42 Ameren Missouri:
Beginning ofperiod $ 11 $ 15 $ 13 $ 16 Bad debt expense 2 2 3 3 Netwrite-offs (1) (1) (4)
End of period -
12 $ 16 $ 12 $ I6 Ameren Illinois:(a)
Beginning of period $ 17 $ 32 $ 16 $ 34 fb)
Bad debt expense 5 (5) (2)
Net write-offs (4) (1 ) (6) (6)
End of period $ 18 $ 26 $ 18 $ 26 (a) Ameren Illinois has rate-adjustment mechanisms that allow it to recover the difference between its actual net bad debt wnte-offs under GAAF including those associated with receivables purchased from alternative retail electric suppliers, and the amount of net bad debt write-offs included in its base rates.
(b) In the three and six months ended June 30, 2021 Ameren Illinois bad debt expense was reduced as a result of state funding received for customer bill assistance.
Supplemental Cash Flow Information Capital expenditures for the six months ended June 30, 2021 at Ameren and Ameren Missouri included wind generation expenditures of
$417 million.
The following table provides noncash financing and investing activity excluded from the statements of cash flows for the six months ended June 30, 2022 and 2021:
June 30, 2022 June 30, 2021 Ameren Ameren Ameren Ameren Ameren Missouri Illinois Ameren Missouri Illinois Investing Accrued capital expenditures $ 408 $ 204 $ 193 $ 434 $ 259 $ I 74 Net realized and unrealized gain/(loss) nuclear decommissioning trust fund (211) (211) 85 85 Financing Issuance of common stock for stock-based compensation $ 31 $ $ $ 33 $ $
Issuance of common stock under the DRAus 8 Asset Retirement Obligations The following table provides a reconciliation of the beginning and ending carrying amount ofAROs for the six months ended June 30, 2022:
Ameren Ameren Missouri Illinois Ameren (a) )b) (a)
BalanceatDecember3i,2021 -
$ 760 $ 4 $ 764 Accretion 15 )c) I5 (C) change in estimates 2 2 (a) )b) (a)
Balance at June 30, 2022 -
S 777 $ 4 $ 781 (a) Balance included $7 million in Other current liabilities on the balance sheet as of both June 30, 2022, and December 31, 2021.
(b) Included in Other deferred credits and liabilities on the balance sheet.
(c) Accretion expense attributable toAmeren Missouri was recorded as a decrease to regulatory liabilities.
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Stock-based Compensation Amerens long-term incentive plan available for eligible employees, the 2014 Omnibus Incentive Compensation Plan (2014 Plan), was replaced prospectively for new grants only by the 2022 Omnibus Incentive Compensation Plan (2022 Plan) effective May 12, 2022. The 2022 Plan provides for a maximum of 8.8 million common shares to be available for grant to eligible employees and directors, and retains many of the features of the 2014 Plan. The 2022 Plan permits the grant of restricted stock, restricted stock units, stock options (incentive stock options and nonqualified stock options), stock appreciation rights, performance awards, cash-based awards and other stock-based awards.
In the first quarter of 2022 under the 2014 Plan, Ameren granted 267,849 performance share units with a grant date fair value of $25 million and I 22,882 restricted share units with a grant date fair value of $1 I million. Awards vest approximately 3 years after the grant date or on a pro-rata basis upon death or eligible retirement. The performance share units vest based on the achievement of certain specified market performance measures (229,566 performance share units) or clean energy transition targets (38,283 performance share units). The exact number of shares issued pursuant to a performance share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the performance goals.
For the six months ended June 30, 2022 and 2021 excess tax benefits associated with the settlement of stock-based compensation awards reduced income tax expense by $5 million in both periods.
Deferred Compensation At June 30, 2022, and December 31 2021 the present value of benefits to be paid for deferred compensation obligations was $89 million and $91 million, respectively, which was primarily reflected in Other deferred credits and liabilities on Amerens consolidated balance sheet.
Operating Revenues As of June 30, 2022 and 2021 our remaining performance obligations for contracts with a term greater than one year were immaterial. The Ameren Companies elected not to disclose the aggregate amount of the transaction price allocated to the performance obligations that are unsatisfied as of the end of the reporting period for contracts with an initial expected term of one year or less.
See Note 14 Segment Information for disaggregated revenue information.
Excise Taxes Ameren Missouri and Ameren Illinois collect from their customers excise taxes, including municipal and state excise taxes and gross receipts taxes that are levied on the sale or distribution of natural gas and electricity. The following table presents the excise taxes recorded on a gross basis in Operating Revenues Electric, Operating Revenues Natural gas and Operating Expenses Taxes other than income taxes on the statements of income for the three and six months ended June 30, 2022 and 2021:
Three Months Six Months 2022 2021 2022 2021 Ameren Missouri $ 39 $ 35 $ 73 $ 66 Ameren Illinois 28 27 73 66 Ameren $ 67 $ 62 $ 146 $ 132 Earnings per Share The following table reconciles the basic weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding for the three and six months ended June 30, 2022 and 2021:
Three Months Six Months 2022 2021 2022 2021 Weighted-average Common Shares Outstanding Basic 258.2 256.1 258.0 255.2 Assumed settlement of performance share units and restricted stock units 1.0 1.1 1.1 1.3 Dilutive effect of forward sale agreements 0.2 0.1 Weighted-average Common Shares Outstanding Dilutedfa) 259.4 257.2 259.2 256.5 (a) There was an immaterial number of anti-dilutive securities excluded from the earnings per diluted share calculations for the three and six months ended June 30, 2022. There were no anti-dilutive securities excluded from the eamings per diluted share calculations for the three and six months ended June 30, 2021.
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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 June 30, 2022 and 2021 Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount. For additional information about our segments, see Note 16 Segment Information under Part II, Item 8, ofthe Form 10-K.
Ameren Ameren Ameren Ameren Illinois Electric Illinois Ameren Intersegment Missouri Distribution Natural Gas Transmission Other Eliminations Ameren Three Months 2022:
Extemairevenues $ 912 $ 504 $ 184 $ 126 $ $ $ 1,726 Intersegment revenues 7 24 (31)
Net income (loss) attributable to (a]
Ameren common shareholders 100 51 6 63 (13) 207 Capital expenditures 392 143 69 160 1 (1) 764 Three Months 2021:
External revenues $ 799 $ 386 $ 168 $ 119 $ $ $ 1,472 Intersegment revenues 10 2 17 (29)
Net income (loss) attributable to (a)
Ameren common shareholders 111 41 8 55 (8) 207 (b) (b)
Capital expenditures 567 129 61 131 (12) 876 Six Months 2022:
External revenues $ 1,720 $ 968 $ 665 $ 252 $ $ $ 3,605 Intersegment revenues 17 1 44 (62)
Net income attributable to Ameren (a] 459 common shareholders 150 100 86 121 2 Capital expenditures 806 281 118 332 3 (2) 1,538 Six Months 2021:
Extemairevenues $ 1,494 $ 797 $ 515 S 232 $ $ $ 3,038 Intersegmentrevenues 19 2 34 (55)
Net income attributable to Ameren common shareholders 158 87 83 102 10 440 (b) 1,763 Capital expenditures 1,101 286 109 272 1 (6)
(a) Ameren Transmission eamings reflect an allocation of financing costs from Ameren (parent).
(b) Includes $224 million and $417 million atAmeren and Ameren Missouri forwind generation expenditures forthe three and six months ended June 30, 2021, respectively.
Ameren Illinois Ameren Illinois Ameren Electric Illinois Natural Ameren Illinois Intersegment Distribution Gas Transmission Eliminations Ameren Illinois Three Months 2022:
Externairevenues $ 504 $ 184 $ 81 $ $ 769 Intersegmentrevenues 24 (24)
Net income available to common shareholder 51 6 46 103 Capital expenditures 143 69 145 357 Three Months 2021:
Externalrevenues $ 388 $ 168 $ 73 $ $ 629 Intersegment revenues 15 (15)
Net income available to common shareholder 41 8 37 86 Capital expenditures 129 61 119 309 37
Ameren Illinois Ameren Electric Illinois Natural Ameren Illinois Intersegment Distribution Gas Transmission Eliminations Ameren Illinois Six Months 2022:
External revenues $ 969 $ 665 $ 159 $ $ 1,793 Intersegment revenues 44 (44)
Net income available to common shareholder 100 86 86 272 Capital expenditures 281 118 300 699 Six Months 2021:
Externalrevenues $ 799 $ 515 $ 138 $ $ 1,452 Intersegment revenues .
31 (31)
Net income available to common shareholder 87 83 65 235 Capital expenditures 286 109 251 646 The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the three and six months ended June 30, 2022 and 2021 Economic factors affect the nature, timing, amount, and uncertainty of revenues and cash flows in a similar manner across customer classes. Revenues from alternative revenue programs have a similar distribution among customer classes as revenues from contracts with customers. Other revenues not associated with contracts with customers are presented in the Other customer classification, along with electric transmission and off-system revenues.
Ameren Ameren Illinois Ameren Electric Ameren Illinois Ameren Intersegment Missouri Distribution Natural Gas Transmission Eliminations Ameren Three Months 2022:
Residential $ 371 $ 284 $ $ $ $ 655 Commercial 298 180 478 Industrial 73 53 126 Other 148 (13) 150 (31) 254 Total electric revenues $ 890 $ 504 $ $ 150 $ (31) $ 1,513 Residential $ 16 $ $ 117 $ $ $ 133 Commercial 8 30 38 Industrial I 11 12 Other 4 26 30 Total natural gas revenues $ 29 $ $ 184 $ $ $ 213 Total revenuesfa) $ 919 $ 504 $ 184 $ 150 $ (31) $ 1,726 Three Months 2021:
Residential $ 328 $ 21 8 $ $ $ $ 546 Commercial 271 127 398 Industrial 71 34 105 Other 119 9 136 (29) 235 Total electric revenues $ 789 $ 388 $ $ 136 $ (29) $ 1,284 Residential $ 11 $ $ 112 $ $ $ 123 Commercial 4 29 33 Industrial 1 3 4 Other ,- 4 24 . 28 Total natural gas revenues $ 20 $ $ 168 $ $ $ 188 Totalrevenues(2) $ 809 $ 388 $ 168 $ 136 $ 1,472 (29L $
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Ameren Illinois Ameren Electric Ameren Illinois Ameren Intersegment Missouri Distribution Natural Gas Transmission Eliminations Ameren Six Months 2022:
Residential $ 703 $ 547 $ $ $ $ 1,250 Commercial 538 338 876 Industrial 130 98 228 Other 257 (14) 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 Totalnaturalgasrevenues $ 109 $ $ 665 $ $ $ 774 Total revenues(8) $ J,737 $ 969 $ 665 $ 296 $ (62) $ 3,605 Six Months 2021:
Residential $ 640 $ 447 $ $ $ $ 1,087 Commercial 487 259 746 Industrial 123 68 191 Other 180 25 266 (55) 416 Total electric revenues S 1 430 $ 799 $ $ 266 $ (55) S 2,440 Residential $ 45 $ $ 363 $ $ $ 408 Commercial 19 93 112 Industrial 2 17 19 Other 17 42 59 Total natural gas revenues $ 83 $ $ 515 $ $ S 598 Total revenuest ) $
1 51 3 $ 799 $ 51 5 $ 266 $ (55) $ 3 038 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three and six months ended June 30, 2022 and 2021:
Ameren Illinois Ameren Ameren Electric Illinois Ameren Missouri Distribution Natural Gas Transmission Ameren Three Months 2022:
Revenues from alternative revenue programs $ $ 41 $ 3 $ (4) $ 40 Other revenues not from contracts with customers (36) 1 1 (34)
Three Months 2021:
Revenues from alternative revenue programs $ (5) $ 34 $ 2 $ 5 $ 36 (a) (a)
Other revenues not from contracts with customers 66 I 67 Six Months 2022:
Revenues from alternative revenue programs $ (6) $ 96 $ (2) $ (3) $ 85 Other revenues not from contracts with customers (36) (a) 3 2 (31) (a)
Six Months 2021:
Revenues from alternative revenue programs $ (1 5) $ 95 $ 5 $ 4 $ 89 69 (a)
Other revenues not from contracts with customers 64 3 2 (a) Includes insurance recoveries related to lost sales associated with the Callaway Energy Center maintenance outage. See Note 9 Callaway Energy Center under Part II, Item 8, ofthe Form 10-K for additional information.
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Ameren Illinois Ameren Illinois Ameren Electric Illinois Ameren Illinois Intersegment Distribution Natural Gas Transmission Eliminations Ameren Illinois Three Months 2022:
Residential $ 284 $ 117 $ $ $ 401 Commercial 180 30 210 Industrial 53 11 64 Other (13) 26 105 (24) 94 Total revenuesfa)
$ 504 $ 184 $ 105 $ (24) $ 769 Three Months 2021:
Residential $ 218 $ 112 $ $ $ 330 Commercial 127 29 156 Industrial 34 3 37 Other 9 24 88 (15) 106 Totalrevenues(a) $ 388 $ 168 $ 88 $ (15) 629 Six Months 2022:
Residential $ 547 $ 486 $ $ $ 1,033 Commercial 338 127 465 Industrial 98 28 126 Other (14) 24 203 (44) 169 Total revenuesfa) $ 969 $ 665 $ 203 $ (44) $ 1,793 Six Months 2021:
Residential $ 447 $ 363 $ $ $ 810 Commercial 259 93 352 Industrial 68 17 85 Other 25 42 169 (31) 205 Totalrevenuesfa) $ 799 $ 515 $ 169 $ (31) $ 1452 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments forthe three and six months ended June 30, 2022 and 2021:
Ameren Illinois Electric Ameren Illinois Ameren Illinois Distribution Natural Gas Transmission Ameren Illinois Three Months 2022:
Revenues from alternative revenue programs $ 41 $ 3 $ (3) $ 41 Other revenues not from contracts with customers I I 2 Three Months 2021:
Revenues from alternative revenue programs $ 34 S 2 $ 2 $ 38 Other revenues not from contracts with customers I 1 Six Months 2022:
Revenues from alternative revenue programs $ 96 $ (2) $ (2) $ 92 Other revenues not from contracts with customers 3 2 5 Six Months 2021:
Revenues from alternative revenue programs $ 95 $ 5 $ 1 $ 101 Other revenues not from contracts with customers 3 2 5 ITEM 2. MANAGEMENTS 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 1O-Q, as well as Managements 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 ofAmeren as a whole. Also see the Glossary of Terms and Abbreviations at the front of this report and in the Form I 0-K.
Ameren, headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Amerens subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on 40
Amerens common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Amerens 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.
S Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois.
I ATXI operates a FERC rate-regulated electric transmission business in the MISO.
Amerens and Ameren Missouris 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 Missouris subsidiaries were created for the ownership of renewable generation projects. Ameren Illinois has no subsidiaries. All tabular dollar amounts are in millions, unless otherwise indicated.
In addition to presenting results of operations and earnings amounts in total, we present certain information in cents per share. These amounts reflect factors that directly affect Amerens earnings. We believe this per share information helps readers to understand the impact of these factors on Amerens earnings per share.
OVERVIEW Net income attributable to Ameren common shareholders was $207 million, or $0.80 per diluted share, in both the three months ended June 30, 2022 and 2021. Net income attributable toAmeren common shareholders in the six months ended June 30, 2022, was $459 million, or
$1 .77 per diluted share, compared with $440 million, or $1 .71 per diluted share, in the year-ago period. Net income for the three and six months ended June 30, 2022, was favorably affected by increased rate base investments across all segments and a higher recognized ROE atAmeren Illinois Electric Distribution and increased retail electric sales volumes atAmeren Missouri, primarily resulting from colderwinter and warmer early summer temperatures experienced in 2022. Net income for the three and six months ended June 30, 2022, compared with the year-ago periods, were unfavorably affected by increased other operations and maintenance expenses not subject to formula rates, riders, or trackers, primarily due to a reduction in the cash surrender value of company-owned life insurance, higher transmission and distribution expenses due to the timing of expenses and disciplined project management, and an increase due to the expiration of contracts relating to refined coal tax credits atAmeren Missouri in 2021. Net income comparisons in both periods were also unfavorably affected by increased financing costs from debt issuances. Earnings per share comparisons in both periods were unfavorably affected by an increase in the weighted-average basic common shares outstanding.
Amerens strategic plan includes investing and operating its utilities in a manner consistent with existing regulatory frameworks, enhancing those frameworks, and advocating for responsible energy and economic policies, as well as creating and capitalizing on opportunities for investment for the benefit of its customers, shareholders, and the environment. Ameren remains focused on disciplined cost management and strategic capital allocation. Ameren invested $1 .5 billion in its rate-regulated businesses in the six months ended June 30, 2022.
The COVID-19 pandemic continues to affect our results of operations, financial position, and liquidity. While our electric sales volumes, excluding the estimated effects of weather and customer energy-efficiency programs, increased in the first six months of 2022, compared to the same period in 2021 they were comparable to pre-pandemic levels at Ameren Missouri and remain below pre-pandemic levels at Ameren Illinois. However, revenues from Ameren Illinois electric distribution business, residential and small nonresidential customers ofAmeren Illinois natural gas distribution business, and Ameren Illinois and ATXIs electric transmission businesses are decoupled from changes in sales volumes. Earnings at Ameren Missouri and those associated with Ameren Illinois large nonresidential natural gas customers are exposed to such changes. There has also been a shift in sales volumes by customer class at both Ameren Missouri and Ameren Illinois, which began in 2020, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect ofthe COVID-19 pandemic on our results of operations, financial position, and liquidity in subsequent periods will depend on its severity and longevity, future regulatory or legislative actions with respect thereto, and the resulting impact on business, economic, and capital market conditions. We continue to assess the impacts the COVID-19 pandemic is having on our businesses, including impacts on electric and natural gas sales volumes, liquidity, bad debt expense, and supply chain operations. For further discussion of these and other matters discussed below, see Note 1 Summary of SignificantAccounting Policies and Note 2 Rate and Regulatory Matters under Part I, Item 1 of this report, and Results of Operations, Liquidity and Capital Resources, and Outlook sections below.
In December 2021 Ameren Missouri filed a motion with the United States District Court for the Eastern District of Missouri to modify a September 201 9 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. In June 2022, Ameren Missouri supplemented its filing with the district court by proposing reduced operations, mostly operating during peak demand times and emergencies until the energy center is retired. The March 31 2024 compliance date contained in the district courts September 2019 remedy order remains in effect unless extended by the district court. In July 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO 41
designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISO, and Ameren Missouri has started design and procurement activities necessary to complete the upgrades and expects to complete the upgrades by late 2025.
The FERC will need to approve a system support resource agreement detailing the manner of continued operation of the Rush Island Energy Center, as well as a request from Ameren Missouri for recovery of non-energy costs under the related MISO tariff. The agreement, if approved, would have a term of 12 months. The system support resource designation and the related agreement are subject to renewal and revision. Any difference between revenues and costs under the MISO tariff is expected to be included in the FAC. The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISC determination of the Rush Island Energy Center as a system support resource or the FERCs approval. While the district court is under no deadline to issue a ruling modifying the remedy order, a decision is expected in the near term. Related to this mailer, in February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouris planned accelerated retirement of the Rush Island Energy Center, including potential impacts on the reliability and cost ofAmeren Missouris service to its customers; Ameren Missouris plans to mitigate the customer impacts of the accelerated retirement; and the prudence ofAmeren Missouris actions and decisions with regard to the Rush Island Energy Center, which is expected to be addressed in the current electric service regulatory rate review, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement of the Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute. See Note 9 Commitments and Contingencies under Part I, Item I, of this report for additional information.
In February 2022, 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 2022. The plan is designed to upgrade Ameren Missouris electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $8.4 billion over the five-year period from 2022 through 2026, with expenditures largely recoverable under the PISA and the RESRAM.
In February 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 150-MW solar generation facility, which is expected to be located in southeastern Illinois and, if approved by the MoPSC, serve customers under Ameren Missouris Renewable Solutions Program. In June 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 200-MW solar generation facility, which is expected to be located in central Missouri and support Ameren Missouris compliance with the state of Missouris requirement of achieving I 5% of retail sales from renewable energy sources, of which 2% must be derived from solar energy sources. The acquisitions are aligned with the 2022 Change to the 2020 IRP, which Ameren Missouri filed with the MoPSC in June 2022, and are subject to certain conditions, including the issuance of certificates of convenience and necessity by the MoPSC, obtaining MISC transmission interconnection agreements, and approval by the FERC. In July 2022, Ameren Missouri filed for certificates of convenience and necessity with the MoPSC for both facilities and expects decisions by March 2023 and April 2023 for the 200-MW facility and the 150-MWfacility, respectively. Depending on the timing of regulatory approvals and the impact of potential sourcing issues resulting from a Department of Commerce investigation of solar panels imported from four Southeast Asian countries initiated in late March 2022 and the detention of certain solar panels sourced from China as a result of the Uyghur Forced Labor Prevention Act that was passed in December 2021, the projects could be completed as early as the fourth quarter of 2024.
In June 2022, Missouri Senate Bill 745 was enacted and will become effective on August 28, 2022. The law extended Ameren Missouris PISA election through December 2028 and allows for an additional five-year extension through December 2033 if requested by Ameren Missouri and approved by the MoPSC, among other things. The law established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1 2024, and will be based on the revenue requirement established in the immediately preceding rate order. The current rate limitation, which is effective through 2023, is a 2.85% cap on the compound annual growth rate in the average overall customer rate per kilowatthour, based on the electric rates that became effective in April 201 7, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 201 8 MoPSC order. The law also established electric and natural gas property tax trackers that allow Ameren Missouri to defer the difference between actual property taxes incurred and related taxes included in customer rates as a regulatory asset or regulatory liability, with the difference expected to be reflected in rate base in a subsequent rate order.
In August 2022, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by
$316 million. The electric rate increase request is based on a 10.2% ROE, a capital structure composed ofSl.9% common equity, a rate base of
$1 I .6 billion, and a test year ended March 31 2022, with certain pro-forma adjustments expected through an anticipated true-up date of December 31 2022. The MoPSC proceeding relating to the proposed electric service rate changes will take place over a period of up to 11 months, with a decision by the MoPSC expected by June 2023 and new rates effective by July 2023.
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In January 2022, Ameren Illinois filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties under an MYRR In April 2022, Ameren Illinois filed a revised request proposing total ROE incentives and penalties of 24 basis points, allocated evenly among eight proposed performance metrics. In May 2022, the ICC staff recommended that the ICC allow ROE incentives and penalties of no less than 20 basis points and no more than 24 basis points, allocated evenly across the number of performance metrics ultimately approved by the ICC. The ICC is required to issue an order on this matter by September 30, 2022.
In April 2022, Ameren Illinois filed its annual electric distribution service performance-based formula rate update with the ICC to be used for 2023 rates. In July 2022, Ameren Illinois filed a revised request seeking to increase its annual revenues for electric distribution service by $84 million. In June 2022, the ICC staff submitted its calculation of the revenue requirement included in Ameren Illinois update filing, recommending a $60 million increase in Ameren Illinois electric distribution service rates. An ICC decision in this proceeding is required by December 2022, with new rates effective in January 2023.
In June 2022, Ameren Illinois filed its annual electric customer energy-efficiency formula rate update to increase its rates by $1 7 million with the ICC. An ICC decision in this proceeding is required by December 2022, with new rates effective January 2023.
In June 2022, the ICC issued an order approving Ameren Illinois revised energy-efficiency plan that includes annual investments in electric energy-efficiency programs of approximately $120 million per year through 2025, which reflects the increased level of annual investments allowed under the IETL. The ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future plan 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.
RESULTS OF OPERATIONS Our results of operations and financial position are affected by many factors. Economic conditions, including those resulting from the COVID 1 9 pandemic discussed below, 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, 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, and the cash surrender value of company-owned life insurance. Almost all ofAmerens 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, ofthis report and Note 2 Rate and Regulatory Matters under Part II, Item 8, of the Form 1 0-K for additional information regarding Ameren Missouris, Ameren Illinois and ATXIs regulatory mechanisms.
We continue to monitor the impacts of the COVID-1 9 pandemic on our businesses, including impacts on electric and natural gas sales volumes, liquidity, supply chain operations, and bad debt expense. Regarding uncollectible accounts receivable, Ameren Illinois electric distribution and natural gas distribution businesses have bad debt riders, which provide for recovery of bad debt write-offs, net of any subsequent recoveries. Ameren Missouri does not have a bad debt rider or tracker, and thus its earnings are exposed to increases in bad debt expense, absent regulatory relief. However, Ameren Missouri has not experienced and does not expect a material impact to earnings from increases in bad debt expense.
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 forAmeren Illinois electric distribution business, and a FAC forAmeren Missouris electric business.
We employ various risk management strategies to reduce our exposure to commodity risk and other risks inherent in our business. The reliability ofAmeren Missouris 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 ofAmerens earnings for the three and six months ended June 30, 2022 and 2021:
Three Months Six Months 2022 2021 2022 2021 Net income attributable to Ameren common shareholders $ 207 S 207 $ 459 $ 440 Earnings per common share diluted 0.80 0.80 1.77 1.71 Net income attributable to Ameren common shareholders was comparable between the three months ended June 30, 2022, and the same period in 2021. Net income increased $10 million and $8 million atAmeren Illinois Electric Distribution andAmeren Transmission, respectively.
The net income increases were offset by net income decreases of $1 I million and $2 million at Ameren Missouri and Ameren Illinois Natural Gas, respectively, and an increase in net loss of $5 million for activity not reported as part of a segment, primarily at Ameren (parent).
Net income attributable to Ameren common shareholders increased $19 million, or 6 cents per diluted share, in the six months ended June 30, 2022, compared with the year-ago period. The increase was dueto net income increases of$19 million, $13 million, and $3 million at Ameren Transmission, Ameren Illinois Electric Distribution, and Ameren Illinois Natural Gas, respectively. These increases were partially offset by an $8 million decrease in net income at Ameren Missouri and an $8 million decrease in the net income for activity not reported as part of a segment, primarily at Ameren (parent).
Earnings per diluted share were favorably affected in the three and six months ended June 30, 2022, compared to the year-ago periods (except where a specific period is referenced), by:
. 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 (6 cents and 10 cents per share, respectively);
I increased electric retail sales at Ameren Missouri, primarily resulting from colder winter temperatures and warmer early summer temperatures experienced in 2022 (estimated at 5 cents and 8 cents per share, respectively);
. increased base rate revenues for the inclusion of previously deferred interest charges pursuant to the December 2021 MoPSC electric rate order, partially offset by lower deferral of interest charges related to infrastructure investments associated with the PISA and RESRAM (2 cents and 5 cents per share, respectively);
S increased Ameren Illinois Natural Gas earnings from investments in qualifying infrastructure recovered under the QIP and higher base rates pursuant to the ICCs January 2021 natural gas rate order (1 cent and 4 cents per share, respectively);
. increased other income, net, primarily due to increased non-service cost components of net periodic benefit income not subject to formula rates or trackers (2 cents per share for the six months ended June 30, 2022);
. the absence in 2022 of the FERCs March 2021 order, primarily related to the historical recovery of materials and supplies inventories, which decreased Ameren Transmission revenues in 2021 (3 cents per share for the six months ended June 30, 2022); and
. higher base rates at Ameren Missouri 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 (2 cents per share for both periods).
Earnings per diluted share were unfavorably affected in the three and six months ended June 30, 2022, compared to the year-ago periods, by:
increased other operations and maintenance expenses not subject to formula rates, riders, or trackers, primarily due to a reduction in the cash surrender value of company-owned life insurance, higher transmission and distribution expenses due to the timing of expenses and disciplined project management, and an increase due to the expiration of contracts relating to refined coal tax credits at Ameren Missouri in 2021 (13 cents and 21 cents per share, respectively);
. increased financing costs, primarily at Ameren (parent) and Ameren Missouri, largely due to higher long-term debt balances (4 cents and 6 cents per 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, ofthis report, and Note 5 Long Term Debt and Equity Financings under Part II, Item 8, ofthe Form 10-K (1 cent and 2 cents per share, respectively).
The cents per share variances above are presented based on the weighted-average basic common shares outstanding in the three and six months ended June 30, 2021 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 Amerens 2022 blended federal and state 44
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.
Below is Amerens table of income statement components by segment for the three and six months ended June 30, 2022 and 2021:
Ameren Illinois Ameren Other I Ameren Electric Illinois Ameren Intersegment Missouri Distribution Natural Gas Transmission Eliminations Ameren Three Months 2022:
Electricrevenues $ 890 $ 504 $ $ 150 $ (31) $ 1,513 Fuel (83) (83)
Purchased power (161) (182) 25 (318)
Electric margins 646 322 150 (6) 1,112 Natural gas revenues 29 184 213 Natural gas purchased for resale (12) (68) (80)
Natural gas margins 17 116 133 Other operations and maintenance expenses (260) (148) (63) (16) (4) (491)
Depreciation and amortization expenses (178) (82) (25) (30) (1) (316)
Taxes other than income taxes (90) (19) (16) (2) (2) (129)
Operating income (loss) 135 73 12 102 (13) 309 Other income, net 24 15 6 4 13 62 Interestcharges (60) (18) (11) (20) (17) (126)
Income (taxes) benefit 2 (18) (1) (23) 4 (36)
Netincome(loss) 101 52 6 63 (13) 209 Noncontrollin interests preferredstock dividends (1) (1) (2)
Net income (loss) attributable toAmeren common shareholders $ 100 $ 51 $ 6 $ 63 $ (13) $ 207 Three Months 2021:
Electricrevenues $ 789 $ 388 $ $ 136 $ (29) $ 1,284 Fuel (173) (173)
Purchased power (50) (99) 20 (129)
Electricmargins 566 289 136 (9) 982 Naturalgasrevenues 20 168 188 Natural gas purchased for resale (5) (60) (65)
Natural gas margins 15 108 123 Otheroperations and maintenanceexpenses (218) (129) (53) (14) 2 (412)
Depreciation and amortization expenses (1 57) (77) (22) (27) (2) (285)
Taxes otherthan income taxes (85) (18) (15) (2) (2) (122)
Operating income (loss) 121 65 18 93 (11) 286 Otherincome, net 24 11 3 2 9 49 Interest charges (36) (19) (10) (20) (11) (96)
Income (taxes) benefit 3 (16) (3) (20) 5 (31)
Net income (loss) I 12 41 8 55 (8) 208 Noncontrolling interests preferred stock dividends (1 )
(1)
Net income (loss) attributable toAmeren common shareholders $ 111 $ 41 $ 8 $ 55 $ (8) $ 207 45
Ameren Illinois Ameren Other!
Ameren Electric Illinois Ameren Intersegment Missouri Distribution Natural Gas Transmission Eliminations Ameren Six Months 2022:
Electric revenues $ 1,628 $ 969 $ $ 296 $ (62) $ 2,831 Fuel (259) (259)
Purchased power (211) (333) 49 (495)
Electricmargins 1,158 636 296 (13) 2,077 Naturalgasrevenues 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 otherthan 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)
Netincome 152 101 86 121 2 462 oINiYid (3)
Net income attributable toAmeren common shareholders $ 150 $ 100 $ 86 $ 121 $ 2 $ 459 Six Months 2021:
Electricrevenues $ 1,430 $ 799 $ $ 266 $ (55) $ 2,440 Fuel (238) (238)
Purchased power (138) (221) = 39 (320)
Electric margins 1,054 578 266 (16) 1,882 Naturalgasrevenues 83 515 598 Natural gas purchased for resale (36) (1 94) (230)
Natural gas margins 47 321 368 Other operations and maintenance expenses (443) (254) (1 09) (30) 4 (832)
Depreciation and amortization expenses (313) (152) (44) (55) (2) (566)
Taxes other than income taxes (162) (38) (40) (4) (6) (250)
Operating income (loss) 183 134 128 177 (20) 602 Otherincome, net 47 19 6 5 18 95 Interest charges (75) (37) (20) (43) (21) (196)
Income (taxes) benefit 5 (28) (31) (37) 33 (58)
Netincome 160 88 83 102 10 443 Noncontrolling interests preferred stock dividends (2) (1) (3)
Net income attributable to Ameren common shareholders $ 1 58 $ 87 $ 83 $ I 02 $ 10 $ 440 46
Below is Ameren Illinois table of income statement components by segment for the three and six months ended June 30, 2022 and 2021:
Ameren Illinois Ameren Ameren Other I Electric Illinois Illinois Intersegment Distribution Natural Gas Transmission Eliminations Ameren Illinois Three Months 2022:
Electricrevenues $ 504 $ $ 105 $ (24) 585 Purchased power (182) 24 (158)
Electric margins 322 105 427 Naturalgasrevenues 184 184 Natural gas purchased for resale (68)
Natural gas margins 116 116 Other operations and maintenance expenses (148) (63) (14) (225)
Depreciation and amortization expenses (82) (25) (21) (128)
Taxes other than income taxes (19) (16) (35)
Operating income (loss) 73 12 70 155 Other income, net 15 6 4 25 Interest charges (18) (11) (12) (41)
Incometaxes (18) (1) (16) (35)
Netincome 52 6 46 104 Preferredstockdividends (1) (1)
Net income attributable to common shareholder $ 51 $ 6 $ 46 $ $ 103 Three Months 2021:
Electric revenues 388 $ $ 88 $ (15) 461 Purchased power (99) 15 (84)
Electric margins 289 88 377 Naturalgasrevenues 168 168 Natural gas purchased for resale (60) (60)
Natural gas margins 108 108 Other operations and maintenance expenses (129) (53) (11) (193)
Depreciation and amortization expenses (77) (22) (18) (117)
Taxes other than incometaxes (1 8) (15) (1) (34)
Operating income (loss) 65 18 58 141 Other income, net 11 3 2 16 lnterestcharges (19) (10) (11) (40)
Income taxes (16) (3) (12) (31)
Net income attributable to common shareholder $ 41 $ 8 $ 37 $ $ 86 47
Ameren Illinois Ameren Ameren Other I Electric Illinois Illinois Intersegment Distribution Natural Gas Transmission Eliminations Ameren Illinois Six Months 2022:
Electricrevenues $ 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)
Netincome 101 86 86 273 Preferred stock dividends (1) (1)
Net income attributable to common shareholder $ 100 $ 86 $ 86 $ $ 272 Six Months 2021:
Electricrevenues $ 799 $ $ 169 $ (31) $ 937 Purchasedpower (221) 31 (190)
Electric margins 578 169 747 Naturalgasrevenues 515 515 Natural gas purchased for resale (194) (194)
Naturalgasmargins 321 321 Other operations and maintenance expenses (254) (109) (24) (387)
Depreciation and amortization expenses (152) (44) (36) (232)
Taxes other than income taxes (38) (40) (2) (80)
Operating income (loss) 134 128 107 369 Other income, net 19 6 5 30 Interest charges (37) (20) (25) (82)
Incometaxes (28) (31) (22) (81)
Net income 88 83 65 236 Preferredstockdividends (1) (1)
Net income attributable to common shareholder $ 87 $ 83 $ 65 $ $ 235 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 GAA 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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Increase by Segment Overall Ameren Overall Ameren Increase of$130 Million Increase of$195 Million Total by Segment(a) (QTD Y0Y) (YTD Y0Y)
Electric Margins
$2,500 $90 $120
$2,077 $80
$100
$2,000 fr[; $1,882 $70
$60 $80
$1,500
$50 $58
$1,112 $60
$982 $40
$1,000 . $33 r
$30 $40 If1I $30
$500 i $20 $14 i $20
$10
$0 $0 $0 QTD QTD YID YID 2022 2021 2022 2021 (a) Includes other/intersegment eliminations of$(6) million, $(9) million, $f13) million, and $(16) million in the three months ended June 30, 2022 and 2021, and six months ended June 30, 2022 and 2021, respectively.
Other/intersegment lAmeren Illinois Electric Distribution iission Natural Gas Margins Increase by Segment Overall Ameren Overall Ameren Increase of$JO Million Increase of $33 Million Total by Segment (QTD Y0Y) (YTD YoY)
$450 $10 $30
$400
$5 2
$8
$350
$20
$300 $6
$250 $15
$200 $10
$2
$150 $2
$100 I
$0
$0
$50
$0 $(2) $(5) j QTD QID YID YID 2022 2021 2022 2021
. Ameren Illinois Natural Ameren Missouri Gas 49
The following tables present the favorable (unfavorable) variations by Ameren segment for electric and natural gas margins for the three and six months ended June 30, 2022, compared with the year-ago periods:
Electric and Natural Gas Margins Ameren Illinois Ameren Other Ameren Electric Illinois Ameren Ilntersegment Three Months Missouri Distribution Natural Gas Transmissionfa) Eliminations Ameren Electric revenue change:
Effect of weather festimate)fb) $ 21 $ $ $ $ $ 21 Base rates (estimate)fc) 59 28 14 101 Off-system sales, capacity, and FAC revenues, net 2 2 Ameren Illinois energy-efficiency program investment revenues 3 3 Other 2 2 4 Cost recovery mechanisms offset in fuel and purchased powerQ4 4 83 (2) 85 Other cost recovery mechanismste) 13 I3 Total electnc revenue change $ 101 $ 116 $ $ 14 $ (2) $ 229 Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather) $ (8) $ $ $ $ $ (8)
Effect of weather (estimate)(b) (4) (4)
Effect of higher net energy costs included in base rates (3) (3)
Transmission services charges (1) = (1)
Other (1) 3 2 Cost recovery mechanisms offset in electric revenue(d)
(4) (83) 2 (85)
Total fuel and purchased powerchange $ (21) $ (83) $ $ $ 5 $ (99)
Net change in electric margins $ 80 $ 33 $ $ 14 $ 3 $ 130 Natural gas revenue change:
Base rates (estimate) $ 2 $ $ $ $ $ 2 QlPrider 6 6 Other 2 2 Cost recovery mechanisms offset in natural gas purchased for resale(d) 7 8 15 Thtnaturgasrevenuecpge S 9 $ 16 $ $ $ 25_
Natural gas purchased for resale change:
Cost recovery mechanisms offset in natural gas revenue(d)
$ (7) $ $ (8) $ $ $ (15)
Total natural gas purchased for resale change $ (7) $ $ (8) $ $ $ (15)
Net change in natural gas margins $ 2 $ $ 8 $ $ $ 10 50
Ameren Illinois Ameren Other Ameren Electric Illinois Ameren Ilntersegment Six Months Missouri Distribution Natural Gas Transmission(a) Eliminations Ameren Electric revenue change:
Effect of weather (estimate)(b) $ 28 $ $ $ $ $ 28 Base rates (estimate)fc) 77 47 30 154 Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA) 4 4 Off-system sales, capacity, and FAC revenues, net 54 54 Ameren Illinois energy-efficiency program investment revenues 6 6 Other 1 2 - 3 Cost recovery mechanisms offset in fuel and purchased powerd) 28 112 (7) 133 Other cost recovery mechanismsfe) 6 3 9 Totalelectric revenue change $ 198 $ 170 $ $ 30 $ (7) $ 391 Fuel and purchased power change:
Energy costs (excluding the estimated effect of weather) $ (55) $ $ $ $ $ (55)
Effect of weather (estimate)fb) (5) (5)
Effect of higher net energy costs included in base rates (3) (3)
Transmission services charges (1) (1)
Other (2) 3 1 Cost recovery mechanisms offset in electric revenuetu)
(28) (1 12) 7 (133)
Total fuel and purchased power change $ (94) $ (1 12) $ $ $ 10 $ (196)
Net change in electric margins $ 104 $ 58 $ $ 30 $ 3 $ 195 Natural gas revenue change:
Base rates (estimate) $ 3 $ $ 3 $ $ $ 6 Change in rate design I I QiPrider 15 15 Other 4 4 Cost recovery mechanisms offset in natural gas purchased for resale 22 121 143 recovery mechanisms(e) 1 6 7 Totalnaturalgasrevenuechange $ 26 $ $ 150 $ $ $ 176 Natural gas purchased for resale change:
Cost recovery mecharnsmsoffsetin natural gas revenuefd) $ (22) $ $ (121) $ $ $ (143)
Total natural gas purchased for resale change $ (22) $ $ (121) $ $ $ (143)
Netchange in natural gas margins $ 4 $ $ 29 $ $ $ 33 (a) Includes an increase in transmission margins of $1 7 million and $34 million at Ameren Illinois for the three and six months ended June 30, 2022, compared with the year-ago periods.
(b) Represents the estimated variation resulting primarily from changes in cooling and heating degree-days on electric and natural gas demand compared with the year-ago periods; this variation is based on temperature readings from the National Oceanic and AtmosphericAdministration weather stations at local airports in our service territories.
(c) ForAmeren 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. ForAmeren Missouri, base rates exclude an increase for the recovery of lost electric margins resulting from the MEEIA customer energy-efficiency programs and an increase 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.
(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 Missoun, 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, ofthis 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.
51
Ameren Amerens electric margins increased $130 million, or 13%, and $1 95 million, or 10%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods, due to increased margins at Ameren Missouri, Ameren Illinois Electric Distribution, and Ameren Transmission, as discussed below. Amerens natural gas margins increased $10 million, or 8%, and $33 million, or 9%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods, due to increased margins at Ameren Illinois Natural Gas and Ameren Missouri, as discussed below.
Ameren Transmission Ameren Transmissions margins increased $14 million, or I 0%, and $30 million, or I I %, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods. Base rate revenues were favorably affected by increased capital investment (+$5 million and
+$10 million, respectively), as evidenced by a 10% increase in rate base used to calculate the revenue requirement, as well as higher recoverable expenses (+$9 million and --$13 million, respectively), and the absence in 2022 of the FERCs March 2021 order (+$Z million) for the six months ended June 30, 2022. See Transmission Formula Rate Revisions in Note 2 Rate and Regulatory Matters under Part I, Item I , of this report for additional information regarding the March 2021 FERC order.
Ameren Missouri Ameren Missouris electric margins increased $80 million, or 14%, and $104 million, or 10%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods. Revenues associated with Cost recovery mechanisms offset in fuel and purchased power increased $4 million and $28 million, respectively, for the three and six months ended June 30, 2022. The increased revenues are fully offset by an increase in fuel and purchased power costs, which increased primarily due to 2022 amortization of costs previously deferred under the FAG that were reflected in customer rates. 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 Missouris 5%
exposure to net energy cost variances under the FAG is reflected within Off-system sales, capacity, and FAG revenues, net and Energy costs (excluding the estimated effect of weather).
The following items had a favorable effect on Ameren Missouris electric margins for the three and six months ended June 30, 2022, compared with the year-ago periods (except where a specific period is referenced):
. The December 2021 MoPSG electric rate order effective February 28, 2022, that resulted in higher electric base rates, excluding the change in base rates for the MEEIA customer energy efficiency programs and the RESRAM, partially offset by higher net energy costs included in base rates, increased margins $56 million and $74 million, respectively. The change in electric base rates is the sum of the change in Base rates (estimate) (+$59 million and --$77 million, respectively) and the Effect of higher net energy costs included in base rates (-$3 million and -$3 million, respectively) in the table above.
. Summer temperatures were warmer as cooling degree days increased 12% for the three months ended June 30, 2022, and winter temperatures were colder as heating degree days increased I % for the three months ended March 31 , 2022. The aggregate effect of weather increased margins an estimated $1 7 million and $23 million, respectively. The change in margins due to weather is the sum of the Effect of weather (estimate) on electric revenues (+$21 million and +$28 million, respectively) and the Effect of weather (estimate) on fuel and purchased power (-$4 million and -$5 million, respectively) in the table above.
, Other cost recovery mechanisms increased margins $13 million and $6 million, respectively, due to increased RESRAM revenues (÷$8 million and +$12 million, respectively) primarily resulting from higher off-system sales recoverable under the RESRAM, increased excise taxes (+$4 million and --$6 million, respectively), and a change in recoverable MEElAprogram costs (+$1 million and -$12 million, respectively).
. Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues increased an estimated
$4 million for the six months ended June 30, 2022. The increase was primarily due to an increase in retail sales volumes, partially offset by a decrease in the average retail price per kilowatthour due to changes in customer usage patterns.
Ameren Missouris electric margins decreased $6 million and $1 million due to Ameren Missouris 5% exposure to net energy cost variances under the FAG for the three and six months ended June 30, 2022, respectively. Net energy costs were higher than those reflected in base rates, primarily because of higher purchased power costs due to higher energy prices and the absence of electric revenues from insurance recoveries related to the Gallaway Energy Genter maintenance outage in 2021 in both periods, partially offset in the six months ended June 30, 2022, by an increase in off-system sales revenue due to higher energy prices and increased generation from the Gallaway Energy Genter. In the three and six months ended June 30, 2022, higher capacity revenues were almost entirely offset by higher capacity costs included in Purchased power on Amerens and Ameren Missouris consolidated income statements, with the increase in both revenues and expenses caused by the capacity prices set in the April 2022 MISO capacity auction, which became effective in June 2022. See Outlook for additional information related to the April 2022 MISO capacity auction. The change in net energy costs is the sum of Off-system sales, capacity and FAG revenues, net (+$2 million and 454 million, respectively) and Energy costs (excluding the estimated effect of weather) (-$8 million and -$55 million, respectively) in the table above.
52
Ameren Missouris natural gas margins increased $2 million, or I 3%, and $4 million, or 9%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods, primarily due to increased base rates as a result of the December 2021 MoPSC gas rate order effective February 28, 2022. Purchased gas costs increased $7 million and $22 million for the three and six months ended June 30, 2022, respectively, due to 2022 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 partially offset by lower natural gas prices in 2022. The increased purchased natural gas costs are fully offset by an increase in natural gas revenues under the PGA rider, 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 $50 million, or 13%, and $92 million, or 12%, forthe three and six months ended June 30, 2022, respectively, compared with the year-ago periods, driven by increased margins at Ameren Illinois Electric Distribution and Ameren Illinois Transmission. Ameren Illinois Natural Gas margins increased $8 million, or 7%, and $29 million, or 9%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods.
Ameren Illinois Electric Distribution Ameren Illinois Electric Distributions margins increased $33 million, or 11%, and $58 million, or 10%, forthe three and six months ended June 30, 2022, respectively, compared with the year-ago periods. Purchased power costs increased $83 million and $112 million for the three and six months ended June 30, 2022, respectively, primarily resulting from higher electric prices. 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 a favorable effect on Ameren Illinois Electric Distributions margins for the three and six months ended June 30, 2022, compared with the year-ago periods:
. Base rates increased due to a higher recognized ROE (+$6 million and +$8 million, respectively), as evidenced by an increase of 79 basis points in the estimated annual average of the monthly elds of the 30-year United States Treasury bonds, increased capital investment (+$2 million and +$4 million, respectively), as evidenced by a 6% increase in rate base used to calculate the revenue requirement, and higher recoverable non-purchased power expenses (+$20 million and +$39 million, respectively), partially offset by the absence in 2022 of revenue requirement reconciliation adjustment true-ups (-$4 million) recorded in the first quarter of 2021 The sum of these changes collectively increased margins $28 million and $47 million, respectively.
. Revenues increased $3 million and $6 million, respectively, 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 increased $8 million, or 7%, and $29 million, or 9%, for the three and six months ended June 30, 2022, respectively, compared with the year-ago periods. Purchased gas costs increased $8 million and $121 million for the three and six months ended June 30, 2022, respectively, due to 2022 amortization of natural gas costs previously deferred under the PGA, driven by a significant increase in cost and customer demand as a result of the extremely cold weather in mid-February 2021 partially offset by lower natural gas costs in 2022.
The increased purchased natural gas costs are fully offset by an increase in natural gas revenues under the PGA rider, 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.
The following items had a favorable effect on Ameren Illinois Natural Gas margins for the three and six months ended June 30, 2022 (except where a specific period is referenced):
Revenues increased $6 million and $1 5 million, respectively, due to additional investment in natural gas infrastructure under the QIP.
. Other cost recovery mechanisms increased revenues $6 million, primarily due to increased revenues for excise taxes, for the six months ended June 30, 2022.
. Revenues increased $3 million in January 2022 due to higher base rates as a result of the January 2021 natural gas rate order.
53
Ameren Illinois Transmission Ameren Illinois Transmissions margins increased $17 million, or 19%, and $34 million, or 20%, forthe three and six months ended June 30, 2022, respectively, compared with the year-ago periods. Ease rate revenues were favorably affected by increased capital investment (+$6 million and +$JJ million, respectively), as evidenced by a 16% increase in rate base used to calculate the revenue requirement, the absence in 2022 of the FERCs March 2021 order(+$7 million) forthe six months ended June 30, 2022, and higher recoverable expenses (--$11 million and +$16 million, respectively). See Transmission Formula Rate Revisions in Note 2 Rate and Regulatory Matters under Part I, Item I of this report for additional information regarding the March 2021 FERC order.
Other Operations and Maintenance Expenses Increase by Segment Overall Ameren Overall Ameren Increase of $79 Million Increase of $720 Million Total by Segment(a) (QTD YoY) (YTD Y0Y)
$1,000 $45 $55
$800 $44 $41
$600 $33
$491
$412 $19
- $400 *
$22
$I
$200 .
$11
- iiU
$2
$0 $0 $0 QTD QTD YTD YTD 2022 2021 2022 2021 (a) IncPudes $16 miPlion and $14 million atAmeren Transmission in thethree months ended June 30, 2022 and 2021, respectively. Also includes other/intersegment eliminations of
$4 million, $(2) million, $7 million, and $(4) million in the three months ended June 30, 2022 and 2021 and in the six months ended June 30, 2022 and 2021 respectively.
C Ameren Missouri Ameren Illinois Natural Gas Otherllntersegment Eliminations I Ameren Illinois EPectric Distribution Ameren Transmission Ameren Other operations and maintenance expenses increased $79 million and $720 million in the three and six months ended June 30, 2022, compared with the year-ago periods. In addition to changes by segments discussed below, other operations and maintenance expenses increased $6 million and $11 million in the three and six months ended June 30, 2022 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, which 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 periods.
54
Ameren Missouri Other operations and maintenance expenses increased $42 million and $49 million in the three and six months ended June 30, 2022, compared with the year-ago periods. The following items increased other operations and maintenance expenses in the three and six months ended June 30, 2022, compared with the year-ago periods (except where a specific period is referenced):
S The cash surrender value of company-owned life insurance decreased $1 2 million and $1 8 million, respectively, primarily because of unfavorable market returns in 2022, compared with favorable market returns in 2021.
I The absence in 2022 of $6 million and $12 million, respectively, in service fees received under refined coal production agreements, as the result of the expiration of refined coal tax credits at the end of 2021 which impact was reflected in electric services rates pursuant to the December 2021 MoPSC rate order.
. Labor and benefit costs increased $7 million and $1 I million, respectively, primarily because of increased pension service costs due to a higher base level of expenses reflected in electric service rates pursuant to the December 2021 MoPSC rate order.
. Transmission and distribution expenditures increased $6 million in both periods, primarily due to disciplined project management and increased storm costs.
The absence of a $5 million deferral to a regulatory asset of certain costs previously incurred related to the COVID-19 pandemic, pursuant to the March 2021 MoPSC orders, which decreased other operations and maintenance expenses in the six months ended June 30, 2021.
. Energy center operating costs increased $3 million in the six months ended June 30, 2022, primarily because of costs related to new wind generation facilities, which are recovered under the RESRAM.
e Customer billing costs increased $2 million in both periods, primarily because credit card fees charged to customers were discontinued in March 2022 pursuant to the December 2021 MoPSC rate order, which incorporated an amount of fees in electric service rates.
The above increases in the six months ended June 30, 2022, compared with the year-ago period, were partially offset by a $12 million decrease in MEEIA customer energy-efficiency program spend as approved by the MoPSC.
Ameren Illinois Other operations and maintenance expenses increased $32 million and $61 million in the three and six months ended June 30, 2022, compared with the year-ago periods, as discussed below. Other operations and maintenance expenses increased $3 million atAmeren Illinois Transmission in the three and six months ended June 30, 2022, compared with the year-ago periods, primarily because of decreases in the cash surrender value of company-owned life insurance related to unfavorable market returns in 2022, compared with favorable market returns in 2021.
Ameten Illinois Electric Distribution Other operations and maintenance expenses increased $19 million and $41 million in the three and six months ended June 30, 2022, compared with the year-ago periods. The following items increased other operations and maintenance expenses in the three and six months ended June 30, 2022, compared with the year-ago periods (except where a specific period is referenced):
I Distribution system expenditures increased $5 million and $1 5 million, respectively, primarily because of projects deferred in 2021 as a result of storm restoration efforts for which the associated costs were deferred as a regulatory asset in 2021.
. The cash surrender value of company-owned life insurance decreased $6 million and $9 million, respectively, primarily because of unfavorable market returns in 2022, compared with favorable market returns in 2021.
I Increased bad debt expense of $2 million and $7 million, respectively, primarily because of increased recovery of bad debt costs allowed by the ICC.
. Injuries and damages increased $4 million in both periods, primarily because of an increase in claims compared with the year-ago periods.
. Amortization of regulatory assets associated with customer energy-efficiency program investments under formula ratemaking increased
$2 million and $4 million, respectively.
Ameren Illinois Natural Gas Other operations and maintenance expenses increased $10 million and $17 million in the three and six months ended June 30, 2022, compared with the year-ago periods, primarily because of increased distribution system expenditures of $5 million and $9 million, respectively, primarily because of a shift from capital to operations and maintenance activity, which is expected to largely reverse in the second half of the year. Other operations and maintenance expenses also increased $3 million and $5 million, respectively, because of decreases in the cash surrender value of company-owned life insurance related to unfavorable market returns in 2022, compared with favorable market returns in 2021.
55
Depreciation and Amortization Expenses Increase (Decrease) by Segment Overall Ameren Overall Ameren Increase of $31 Million Increase of $49 Million Total by Segmentfa) (QID Y0Y) (YTD Y0Y)
$615 $25 $40
$600 -
$21
$20
$30
$450 $15 T $10 $20
$300
$5
$5 $11
$3 $3
$0
$ (5)
QTD QTD YID YTD 2022 2021 2022 2021 (a) Includes other/intersegment eliminations of$1 million, $2 million, $2 million, and $2 million in the three months ended June 30, 2022 and 2021, and in the six months ended June 30, 2022 and 2021, respectively Ameren Missouri Illinois Natural Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission Depreciation and amortization expenses increased $31 million, $21 million, and $11 million in the three months ended June 30, 2022, and
$49 million, $29 million, and $20 million in the six months ended June 30, 2022, compared with the year-ago periods, atAmeren, Ameren Missouri, and Ameren Illinois, respectively, primarily because of additional property, plant, and equipment investments across their respective segments. Amerens and Ameren Missouris depreciation and amortization expenses for the three and six months ended June 30, 2022, compared with the year-ago periods, were affected by the following, which include the effect ofthe additional investments:
. Depreciation and amortization rate changes pursuant to the December 2021 MoPSC electric rate order, which increased depreciation and amortization expenses by $17 million and $23 million, respectively.
. Increased depreciation and amortization expenses of $1 7 million and $23 million, respectively, for amounts previously deferred under the PISA and RESRAM and subsequently reflected in base rates pursuant to the December 2021 MoPSC electric rate order, largely due to investments in wind generation.
. Fewer deferrals of depreciation and amortization expenses of $15 million in both periods due to less property, plant, and equipment eligible for recovery under the PISA and RESRAM as a result ofthe December 2021 MoPSC electric rate order.
. The net deferral related to the Meramec Energy Center retirement, which decreased depreciation and amortization expenses by $15 million and $20 million, respectively, pursuant to the December 2021 MoPSC electric rate order.
. The net under-recovery of RESRAM eligible expenses, which decreased depreciation and amortization expenses by $9 million and
$14 million, respectively.
56
Taxes Other Than Income Taxes Increase by Segment Overall Ameren Overall Ameren Increase of $7 Million Increase of $21 Million Total by Segmentfa) (QTD Y0Y) (YTD Y0Y)
$280 $271 $6 $15
$13
$240 .
$5 j$5
$12
$200
$4 U) $9 0
$129 $3 $7
$122
$120
$6
$2
$80
$1 $1 $3
$1 11$-
$40
(
$0 $0 $0 QTD QID YID YTD 2022 2021 2022 2021 (a) Includes $2 million, $2 million, $4 million, and $4 million at Ameren Transmission in the three months ended June 30, 2022 and 2021 and in the six months ended June 30, 2022 and 2021 respectively. Also includes other/intersegmenteliminations of $2 million, $2 million, $6 million, and $6 million in the three months ended June 30, 2022 and 2021 and in the six months ended June 30, 2022 and 2021 respectively.
Ameren Illinois Natural Ameren Missouri Gas Other/Intersegment Eliminations B Ameren Illinois Electric Distribution Ameren Transmission Taxes other than income taxes increased $7 million in the three months ended June 30, 2022, compared with the year-ago period, primarily because of a $4 million increase in excise taxes atAmeren Missouri, primarily because of increased sales. Taxes other than income taxes increased $21 million in the six months ended June 30, 2022, compared with the year-ago period, primarily because of $7 million increases in excise taxes at both Ameren Missouri and Ameren Illinois Natural Gas, primarily because of increased sales. Taxes other than income taxes also increased $6 million in the six months ended June 30, 2022, compared with the year-ago period, atAmeren Missouri because of increased property taxes, primarily resulting from higher assessed values and lower property tax refunds.
57
Other Income, Net Increase by Segment Overall Ameren Overall Ameren Increase of$13 Million Increase of$27 Million Total by Segment(a) (QTD Y0Y) (YTD Y0Y)
$140 $5 $15
$122
$120 $4 $4 $12 U)
$100
$4
$3 I $12
$80 0
$62
$60
$2
$49
$40
$1
$20
$0 $0 QID QID YTD YID 2022 2021 2022 2021 (a) ncludes $4 million and $2 million atAmeren Transmission in the three months ended June 30, 2022 and 2021, respectively.
I Ameren Missouri Arneren Illinois Natural Other/Intersegment Eliminations I AmereniNinois Electnc rAmeren Transmission Other income, net, increased $13 million in the three months ended June 30, 2022, compared with the year-ago period, primarily because of increases in the non-service cost component of net periodic benefit income of $5 million, $5 million, and $2 million atAmeren Illinois Electric Distribution, activity not reported as part of a segment, and Ameren Illinois Natural Gas, respectively. Other Income, net, increased $27 million in the six months ended June 30, 2022, compared with the year-ago period, primarily because of increases in the non-service cost component of net periodic benefitincome of$1O million, $9 million, and $4 million forAmeren Illinois Electric Distribution, activity notreported as part of a segment, and Ameren Illinois Natural Gas, respectively.
See Note 5 Other Income, Net, under Part I, Item I ofthis report for additional information. See Note I I Retirement Benefits under Part I, Item I of this report for more information on the non-service cost components of net periodic benefit income.
58
Interest Charges Increase (Decrease) by Segment Overall Ameren Overall Ameren Increase of $30 Million Increase of $34 Million Total by Segment (QTD Y0Y) (YTD Y0Y)
$240 $30 $30
$25 $25 $24
$200
$20 $20
$160 I
0
$15 $15
_$120
$10 $10
$80
$5 $5
$2
$40
$0 $0 --
III
$(1) $(1) $(f)
$0 $ (5) $(5) J QTD QTD YTD YID 2022 2021 2022 2021 Ameren Missouri Ameren Illinois Natural Other/Intersegment Eliminations Gas
. Ameren Illinois Electric Distribution Ameren Transmission Interest charges increased $30 million and $34 million in the three and six months ended June 30, 2022, compared with the year-ago periods. The following items increased interest charges in the three and six months ended June 30, 2022, compared with the year-ago periods:
Interest charges at Ameren and Ameren Missouri 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 $1 5 million and $12 million, respectively.
lssuances of long-term debt at Ameren Missouri in June 2021 and April 2022 collectively increased interest charges by $8 million and $10 million, respectively.
lssuances of long-term debt at Ameren (parent) in March and November 2021 collectively increased interest charges by $2 million and $6 million, respectively.
Income Taxes The following table presents effective income tax rates for the three and six months ended June 30, 2022 and 2021:
Three Months(2) Six MOflthS(aJ 2022 2021 2022 2021 Ameren 15% 13% 13% 12%
Ameren Missouri (2)% (3)% (3)% (3)%
Ameren Illinois 25 % 26 % 26 % 25 %
Ameren Illinois Electric Distribution 26 % 25 % 25 % 24 %
Ameren Illinois Natural Gas 25 % 29 % 27 % 27 %
Ameren Illinois Transmission 25 % 25 % 26 % 25 %
Ameren Transmission 26 % 26 % 26 % 26 %
(a) Estimate ofthe annual effective income tax rate adjusted to reflect the tax effect of items discrete to the three and six months ended June 30, 2022 and 2021.
59
See Note I 2 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 lower atAmeren Illinois Natural Gas in the three months ended June 30, 2022, compared with the year-ago period, primarily because of higher amortization of excess deferred taxes.
LIQUIDITYAND 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 ofAmeren 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 ofAmeren Missouri and Ameren Illinois, with capital contributions from Ameren (parent). As of June 30, 2022, 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 ofthe Form 1 0-K for the year ended December 31 2021 In April and May 2022, Ameren Illinois conducted procurement events, administered by the IPA, to purchase energy products and acquire capacity through May 2025. As a result, Ameren and Ameren Illinois estimated minimum purchase obligations for purchased power increased by $0.5 billion in total over the period of June 2022 through May 2025.
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 I 0-K and Note 4 Long-term Debt and Equity Financings under Part I, Item I ofthis 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 DRPIus and employee benefit plans and expects to continue to do so through at least 2026. Ameren expects these issuances to provide equity of about $100 million annually. In addition, in 2021 Ameren established an ATM program under which Ameren may offer and sell from time to time up to $750 million of its 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 June 30, 2022. Ameren has entered into multiple forward sale agreements under the ATM program with various counterparties relating to 5.8 million shares of common stock. As of June 30, 2022, Ameren could have settled the forward sale agreements with physical delivery of 5.6 million shares of common stock to the respective counterparties in exchange for cash of $500 million. As of June 30, 2022, Ameren had approximately $90 million of common stock available under the ATM program, which takes into account the forward sale agreements in effect as of June 30, 2022. Ameren expects to settle approximately $300 million of the forward sale agreements by December 31 2022. Ameren plans to issue approximately $300 million of equity each year from 2022 to 2026 in addition to issuances under the DRPIus and employee benefit plans. Ameren expects its equity to total capitalization ratio to be approximately 45% through December 31 2026, 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 I of this report for additional information on the ATM program, including the forward sale agreements under the ATM program relating to common stock.
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 June 30, 2022, for Ameren 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 .3 billion at June 30, 2022. See Credit Facility Borrowings and Liquidity for additional information.
The following table presents net cash provided by (used in) operating, investing, and financing activities for the six months ended June 30, 2022 and 2021 Net cash Provided By Net cash Used In Net Cash Provided By OperatingActivities Investing Activities Financing Activities 2022 2021 Variance 2022 2021 Variance 2022 2021 Variance Ameren $ 872 $ 436 $ 436 $ (1,552) $ (1,760) $ 208 $ 686 $ 1,290 $ (604)
Ameren Missouri 181 224 (43) (818) (1,053) 235 636 701 (65)
Ameren Illinois 675 286 389 (699) (668) (31) 37 477 (440)
Cash Flows from Operating Activities Our cash provided by operating activities is affected by fluctuations oftrade accounts receivable, inventories, and accounts and wages 60
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 rate proceeding. 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, such as increased demand resulting from the extremely cold weather in mid-February 2021 discussed below, 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, forAmeren Missouri, underthe FAC (Ameren Missouri PGA $53 million, FAC $50 million; Ameren Illinois PGA $221 million).
Ameren Missouris 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 is collecting the PGA under-recovery over 18 months beginning April 2021.
Ameren Amerens cash provided by operating activities increased $436 million in the first six months of 2022, compared with the year-ago period.
The following items contributed to the increase:
. A $574 million increase resulting from increased customer collections and decreased expenditures under the PGA and FAC, primarily as a result of the significant increase from customer demand and prices for natural gas and electricity experienced in mid-February 2021 due to extremely cold weather, a net increase attributable to other regulatory recovery mechanisms, and higher customer collections resulting from base rate increases pursuant to Ameren Missouris December 2021 electric rate order.
. A $20 million decrease in coal inventory levels at Ameren Missouri, as less coal was purchased in 2022 due to service-related delivery disruptions.
. A$14 million decrease in major storm restoration costs atAmeren Illinois, primarily due to a January 2021 storm.
. An $11 million decrease in payments to settle ARO liabilities, primarily related to the closure ofAmeren Missouris CCR storage facilities.
. An $8 million decrease in the cost of natural gas held in storage, primarily at Ameren Illinois, because of an increase in withdrawals between periods.
The following items partially offset the increase in Amerens cash from operating activities between periods:
. A $77 million increase in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.
I A $39 million increase in payments for nuclear refueling and maintenance outages at Ameren Missouris Callaway Energy Center. There was no scheduled refueling and maintenance outage in 2021.
. A $30 million increase in purchases of materials and supplies inventories to support operations in 2022 as levels were increased to mitigate against any potential supply disruptions.
e A $23 million increase in payments for certain cloud computing arrangements.
. The absence in 2022 of$15 million in service fees received under refined coal production agreements atAmeren Missouri, as the result of the expiration of refined coal tax credits at the end of 2021.
I A $20 million increase in interest payments, primarily due to an increase in the average outstanding debt.
a A $1 3 million increase in property tax payments at Ameren Missouri, primarily due to higher assessed property tax values.
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Ameren Missouri Ameren Missouris cash provided by operating activities decreased $43 million in the first six months of 2022, compared with the year-ago period. The following items contributed to the decrease:
. An $88 million increase in net collateral posted with counterparties, primarily due to changes in the market prices of power, natural gas, and other fuels.
. A $67 million decrease in income tax refunds from Ameren (parent) pursuant to the tax allocation agreement, primarily due to higher taxable income in 2022.
A $39 million increase in payments for nuclear refueling and maintenance outages at the Callaway Energy Center. There was no scheduled refueling and maintenance outage in 2021.
0 A $20 million increase in purchases of materials and supplies inventories to support operations in 2022 as levels were increased to mitigate against any potential supply disruptions.
. The absence in 2022 of $1 5 million in service fees received under refined coal production agreements, as the result of the expiration of refined coal tax credits at the end of 2021.
. A $13 million increase in property tax payments, primarily due to higher assessed property tax values.
a A $12 million increase in payments for certain cloud computing arrangements.
S A $9 million increase in interest payments, primarily due to an increase in the average outstanding debt.
The following items partially offset the decrease in Ameren Missouris cash from operating activities between periods:
I A $207 million increase from higher customer collections and decreased expenditures under the FAC and PGA due to the significant increase from customer demand and prices for natural gas and electricity experienced in mid-February 2021 due to extremely cold weather and higher customer collections resulting from base rate increases pursuant to the December 2021 electric rate order.
A $20 million decrease in coal inventory levels, as less coal was purchased in 2022 due to service-related delivery disruptions.
. An $1 I million decrease in payments to settle ARO liabilities, primarily related to the closure of CCR storage facilities.
Ameren Illinois Ameren Illinois cash provided by operating activities increased $389 million in the first six months of 2022, compared with the year-ago period. The following items contributed to the increase:
a A $368 million increase resulting from increased customer collections and decreased expenditures under the PGA, primarily as a result of the significant increase from customer demand and prices for natural gas experienced in mid-February due to extremely cold weather and a net increase attributable to other regulatory recovery mechanisms.
a A $14 million decrease in major storm restoration costs, primarily due to a January 2021 storm.
a An $1 I million increase in net collateral received from counterparties, primarily due to changes in the market prices of power and natural gas.
a An $8 million decrease in the cost of natural gas held in storage because of an increase in withdrawals between periods.
The following items partially offset the increase in Ameren Illinois cash from operating activities between periods:
a A $14 million increase in payments for certain cloud computing arrangements.
a A $1 0 million increase in purchases of materials and supplies inventories to support operations in 2022 as levels were increased to mitigate against any potential supply disruptions.
Cash Flows from Investing Activities Amerens cash used in investing activities decreased $208 million during the first six months of 2022, compared with the year-ago period, primarily as a result of a $225 million decrease in capital expenditures, largely resulting from a reduction in expenditures related to wind generation assets at Ameren Missouri, partially offset by increased expenditures for electric delivery infrastructure upgrades at Ameren Missouri and for transmission projects at Ameren Illinois. The decrease in Amerens cash used in investing activities was partially offset by an $1 8 million increase due to the timing of nuclear fuel expenditures at Ameren Missouri.
Ameren Missouris cash used in investing activities decreased $235 million during the first six months of 2022, compared with the year-ago period, primarily as a result of a $295 million decrease in capital expenditures, primarily resulting from a reduction in expenditures related to wind generation assets partially offset by increased expenditures for electric delivery infrastructure upgrades. This decrease was partially offset by a
$47 million return of net money pool advances in the first six months of 2021 and an $1 8 million increase due to the timing of nuclear fuel expenditures.
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Ameren Illinois cash used in investing activities increased $31 million during the first six months of 2022, compared with the year-ago period, primarily as a result of a $53 million increase in capital expenditures, largely related to transmission projects. This increase was partially offset by a $20 million decrease in Ameren Illinois net money pool advances.
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. Due to extremely cold winterweather in mid-February 2021 Ameren Missouri and Ameren Illinois experienced higher than anticipated commodity costs for natural gas purchased for resale and purchased power, which contributed to the acceleration of the timing of certain planned 2021 debt issuances.
Amerens cash provided by consolidated financing activities decreased $604 million during the first six months of 2022, compared with the year-ago period. During the first six months of 2022, Ameren utilized proceeds of $524 million of long-term debt to repay then-outstanding short-term debt and for near-term capital expenditures. In addition, during the first six months of 2022, Ameren utilized proceeds from net commercial paper issuances of $475 million along with cash provided by operating activities to fund, in part, investing activities. In comparison, during the first six months of 2021 Ameren utilized proceeds from the issuance of $1 423 million of long-term debt for general corporate purposes, including to repay then-outstanding short-term debt, including short-term debt in connection with the increased purchases for natural gas for resale and purchased power costs 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, and to fund, in part, investing activities. During the first six months of 2021, Ameren repaid net short-term debt of $59 million. In addition, Ameren received aggregate cash proceeds of $258 million from the issuance of common stock under the ATM program, the DRPlus, and the 401(k) plan and the settlement of the remaining portion of the 2019 forward sale agreement. These proceeds were used to fund a portion ofAmeren Missouris wind generation investments and to fund, in part, other investing activities. During the first six months of 2022, Ameren paid common stock dividends of $305 million, compared with $282 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 Missouris cash provided by financing activities decreased $65 million during the first six months of 2022, compared with the year-ago period. 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 near-term capital expenditures. In addition, during the first six months of 2022, Ameren Missouri utilized proceeds from net commercial paper issuances of$120 million along with cash provided by operating activities to fund, in part, investing activities. In comparison, during the first six months of 2021 Ameren Missouri utilized net proceeds from the issuance of long-term debt of $524 million to repay then-outstanding short-term debt, including short-term debt incurred in connection with the increased purchases for natural gas for resale and purchased power costs 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. Additionally, proceeds from the issuance of long-term debt and capital contributions of $183 million from Ameren (patent) were used to fund a portion of wind generation investments and to fund, in part, investing activities during the first six months of 2021.
Ameten Illinois cash provided by financing activities decreased $440 million during the first six months of 2022, compared with the year-ago period. During the first six months of 2022, Ameren Illinois utilized proceeds from net commercial paper issuances of $38 million and cash provided by operating activities to fund, in part, investing activities. In comparison, during the first six months of 2021 Ameren Illinois utilized net proceeds from the issuance of long-term debt of $449 million to repay then-outstanding short-term debt, including short-term debt incurred in connection with the increased purchases for natural gas for resale and purchased power costs 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, and to fund, in part, investing activities. Ameren Illinois also received a $70 million capital contribution from Ameren (parent) during the first six months of 2021 In.
addition, Ameren repaid $1 9 million of money pool borrowings and redeemed $13 million of preferred stock during the first six months of 2021.
See Long-term Debt and Equity in this section for additional information on maturities and issuances of long-term debt, issuances of common stock, and redemptions of preferred stock.
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Credit Facility Borrowings and Liquidity The following table presents Amerens consolidated liquidity as of June 30, 2022:
Available at June 30, 2022 Ameren (parent) and Ameren Missouri:
Missouri CreditAgreement borrowing capacity
$ I 200 Less: Ameren (patent) commercial paper outstanding 382 Less: Ameren Missouri commercial paper outstanding 285 Less: Ameren Missouri letters of credit 2 Missouri CreditAgreement subtotal 531 Ameren (parent) and Ameren Illinois:
Illinois CreditAgreement borrowing capacity 1100 Less: Ameren (patent) commercial paper outstanding 213 Less: Ameren Illinois commercial paper outstanding 141 Illinois CreditAgreement subtotal 746 Subtotal
$ 1,277 Add: Cash and cash equivalents 7 Net Available Liquidityiai 1,284 (a) Does not include Amerens 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 $2.3 billion of credit until maturity in December 2025. See Note 3 Short-term Debt and Liquidity under Part I, Item I of this report for additional information on the Credit Agreements. During the six months ended June 30, 2022, 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 that 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 ofthis report for additional information on credit agreements, commercial paper issuances, Amerens money pool arrangements and related borrowings, and relevant interest rates.
The issuance of short-term debt securities by Amerens utility subsidiaries is subject to FERC approval under the Federal Power Act. In March 2022, the FERC issued an order authorizing Ameren Missouri to issue up to $1 billion of short-term debt securities through March 2024.
In 2020, the FERC issued an order authorizing Ameren Illinois to issue up to $1 billion of short-term debt securities through September 2022. In 2021 the FERC issued an order authorizing ATXI to issue up to $300 million of short-term debt securities, which expires in July 2023.
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-tenn Debt and Equity The following table presents issuances (net of any issuance premiums or discounts) of long-term debt and equity and redemptions of preferred stock for the six months ended June 30, 2022 and 2021:
Month Issued, Redeemed, or Matured 2022 2021 Issuances of Long-term Debt Ameren:
I .75% Senior unsecured notes due 2028 March $ $ 450 Ameren Missouri:
3.90% First mortgage bonds due 2052 (green bonds) April 524 2.15% First mortgage bonds due 2032 (green bonds) June 524 Ameren Illinois:
2.90% First mortgage bonds due 2051 (green bonds) June 349 0.375%Firstmortgagebondsdue2o23 June 100 TotalAmeren long-term debt issuances $ 524 $ I 423 Issuances of Common Stock Ameren:
DRPIus and 401(k) (a) Various $ 17 (b)
$ 24 August 201 9 forward sale agreement (c) February 113 AlMprogramtd) Various 121 Total Ameren common stock issuances (e) $ J7 $ 258 Redemptions of Preferred Stock Ameren Illinois:
6.625% Series March $ $ 12 7.75% Series March I Total Ameren Illinois preferred stock redemptions $ $ 13 (a) Ameren issued a total of 0.3 million and 0.3 million shares of common stock under its DRPIu5 and 401(k) plan in the six months ended June 30, 2022 and 2021 respectively.
(b) Excludes an $8 million receivable at June 30, 2022.
(c) Ameren issued 1 .6 million shares of common stock to settle the remainder of the August 201 9 forward sale agreement.
(d) Ameren issued I .4 million shares of common stock under the ATM program.
(e) Excludes 0.4 million and 0.5 million shares of common stock valued at $31 million and $33 million issued for no cash consideration in connection with stock-based compensation for the six months ended June 30, 2022 and 2021 respectively.
See Note 4 Long-term Debtand Equity Financings under Part I, Item 1, ofthis report for additional information, including proceeds from issuances of long-term debt, including Ameren Missouris April 2022 issuance of first mortgage bonds, the use of those proceeds, Amerens forward equity sale agreements, and the ATM program.
Indebtedness Provisions and Other Covenants At June 30, 2022, 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 I 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, ofthe Form 10-K for a discussion of provisions, applicable cross-default provisions, and covenants contained in our credit agreements, in ATXIs 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 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 markets, could negatively affect our ability to maintain and expand our businesses. After assessing its 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 markets on reasonable terms. However, events beyond Amerens, Ameren Missouris, and Ameren Illinois control may create uncertainty in the capital markets or make access to the capital markets uncertain or limited. Such events could increase our cost of capital and adversely affect our ability to access the capital markets.
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Dividends The amount and timing of dividends payable on Amerens common stock are within the sole discretion ofAmerens board of directors.
Amerens board of directors has not set specific targets or payout parameters when declaring common stock dividends, but it considers various factors, including Amerens overall payout ratio, payout ratios of our peers, projected cash flow and potential future cash flow requirements, historical earnings and cash flow, projected earnings, impacts of regulatory orders or legislation, and other key business considerations. Ameren expects its dividend payout ratio to be between 55% and 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 June 30, 2022, none of these circumstances existed atAmeren, Ameren Missouri, orAmeren 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 six months ended June 30, 2022 and 2021:
Six Months 2022 2021 Ameren $ 305 $ 282 ATXI 32 Credit Ratings Our credit ratings affect our liquidity, our access to the capital markets 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 Moodys and S&P, as applicable, effective on the date of this report:
Moodys S&P Ameren:
Issuer/corporate credit rating Baal BBB+
Seniorunsecureddebt Baal BBS Commercial paper P-2 A-2 Ameren Missouri:
Issuer/corporate credit rating Baal BBB+
Secured debt A2 A Senior unsecured debt Baal Not Rated commercial paper P-2 A-2 Ameren Illinois:
Issuer/corporate credit rating A3 BBB+
Secured debt Al A Senior unsecured debt A3 EBB-i-commercial paper P-2 A-2 ATXI:
Issuer credit rating A2 Not Rated Senior unsecured debt A2 Not Rated A credit rating is not a recommendation to buy, sell, or hold securities. It should be evaluated independently of any other rating. Ratings are subject to revision or withdrawal at any time by the rating organization.
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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 $222 million, $199 million, and $23 million forAmeren, Ameren Missouri, and Ameren Illinois, respectively, and cash collateral posted by external parties were $75 million, $1 5 million, and $60 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, at June 30, 2022. A sub-investment-grade issuer or senior unsecured debt rating (below Baa3 from Moods/s or below BBB- from S&P) at June 30, 2022, could have resulted in Ameren, Ameren Missouri, orAmeren Illinois being required to post additional collateral or other assurances for certain trade obligations amounting to $166 million, $89 million, and $77 million, respectively.
Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at June 30, 2022, if market prices were 15% higher or lower than June 30, 2022 levels in the next I 2 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 compans liquidity, of collateral or provide other assurances for certain trade obligations.
OUTLOOK Below are some key trends, events, and uncertainties that may reasonably affect our results of operations, financial condition, or liquidity, as well as our ability to achieve strategic and financial objectives, for 2022 and beyond. For additional information regarding recent rate orders, lawsuits, and pending requests filed with state and federal regulatory commissions, including those discussed below, see Note 2 Rate and Regulatory Matters under Part I, Item 1, ofthis report and Note 2 Rate and Regulatory Matters under Part II, Item 8, ofthe Form 10-K.
Operations In the first half of 2022, our sales volumes, which have been, and continue to be, affected by the COVID-1 9 pandemic, among other things, increased compared to the same period in 2021 excluding the estimated effects of weather and customer energy-efficiency programs. While total sales volume levels at Ameren Missouri were comparable to pre-pandemic levels for the first six months of 2022, Ameren Illinois sales remain below pre-pandemic levels. However, revenues from Ameren Illinois electric distribution business, residential and small nonresidential customers ofAmeren Illinois natural gas distribution business, and Ameren Illinois and ATXIs electric transmission businesses are decoupled from changes in sales volumes. There has also been a shift in sales volumes by customer class at both Ameren Missouri and Ameren Illinois, which began in 2020, with an increase in residential sales, and a decrease in commercial and industrial sales.
The continued effect of the COVID-1 9 pandemic on our results of operations, financial position, and liquidity in subsequent periods will depend on its severity and longevity, future regulatory or legislative actions with respect thereto, and the resulting impact on business, economic, and capital market conditions.
S The PISA permits Ameren Missouri to defer and recover 85% of the depreciation expense and earn a return at the applicable WACC on investments in certain property, plant, and equipment placed in service, and not included in base rates. The regulatory asset for accumulated PISA deferrals also earns a return at the applicable WACC, with all approved PISA deferrals added to rate base prospectively and recovered over a period of 20 years following a regulatory rate review. Additionally, under the RESRAM, Ameren Missouri is permitted to recover the 1 5% 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 Missouris 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 1 5% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. Ameren Missouri defers its cost of debt relating to PISA eligible investments as an offset to interest charges with the difference between the applicable WACC and its cost of debt recognized in revenues when recovery of such deferrals is reflected in customer rates. As a result of the PISA election, additional provisions of the law apply to Ameren Missouri, including limitations on electric customer rate increases. Ameren Missouri does not expect to exceed these rate increase limitations in 2022. In June 2022, Missouri Senate Bill 745 was enacted and will become effective on August 28, 2022. The law extended Ameren Missouris PISA election through December 2028 and allows for an additional five-year extension through December 2033 if requested byAmeren Missouri and approved by the MoPSC, among other things. The law established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation will be effective for revenue requirements approved by the MoPSC after January 1 2024, and will be based on the revenue requirement established in the immediately preceding rate order. The current rate limitation, which is effective through 2023, is a 285% 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 201 7, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 2018 MoPSC order.
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In 201 8, the MoPSC issued an order approving Ameren Missouris MEEIA 2019 plan. The plan includes a portfolio of customer energy-efficiency and demand response programs through December 2023 and low-income customer energy-efficiency programs through December 2024, along with a rider. Ameren Missouri intends to invest approximately $360 million over the life of the plan, including
$80 million in 2022 and $75 million in 2023. The plan includes the continued use ofthe MEEIA rider, which allows Ameren Missouri 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 goals were achieved for 2021 and are achieved for 2022, additional revenues of $24 million would be recognized in 2022, and, if target goals are achieved for 2023, additional revenues of $13 million would be recognized in 2023.
S In August 2022, Ameren Missouri filed a request with the MoPSC seeking approval to increase its annual revenues for electric service by
$316 million. The MoPSC proceeding relating to the proposed electricservice rate changes will take place over a period of up to 1 1 months, with a decision by the MoPSC expected by June 2023 and new rates effective by July 2023. Ameren Missouri cannot predict the level of any electric service rate change the MoPSC may approve, whether the requested regulatory recovery mechanisms will be approved, or whether any rate change that may eventually be approved will be sufficient forAmeren Missouri to recover its costs and earn a reasonable return on its investments when the rate change goes into effect.
In December 2021 the MoPSC issued an order in Ameren Missouris 2021 electric service regulatory rate review, resulting in an increase of
$220 million to Ameren Missouris annual revenue requirement for electric retail service. As a result of this order, Ameren Missouri expects a year-over-year increase to 2022 earnings, compared to 2021 primarily in the third quarter of 2022 due to seasonal electric customer rates and higher demand during the summer. Ameren Missouri expects earnings to increase approximately $23 million in the third quarter of 2022, compared to the same period in 2021.
Ameren Illinois and ATXI use a forward-looking rate calculation with an annual revenue requirement reconciliation for each companys electric transmission business. Based on expected rate base and the currently allowed 1 0.52% ROE, which includes a 50 basis point incentive adder for participation in an RTO, the revenue requirements included in 2022 rates forAmeren Illinois and ATXIs electric transmission businesses are $422 million and $1 95 million, respectively. These revenue requirements represent an increase in Ameren Illinois revenue requirement of $42 million and a decrease in ATXIs revenue requirement of $5 million from the revenue requirements reflected in 2021 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 ATXIs cash receipts during 2022, but will not determine their respective electric transmission service operating revenues, which will instead be based on 2022 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 an appeal filed with the United States Court ofAppeals for the District of Columbia Circuit. Depending on the outcome ofthe appeal, the transmission rates charged during previous periods and the currently effective rates may be subject to change. Additionally, in March 201 9, the FERC issued a Notice of Inquiry regarding its transmission incentives policy. In March 2020, the FERC issued a Notice of Proposed Rulemaking on its transmission incentives policy, which addressed many of the issues in the Notice of Inquiry on transmission incentives. The Notice of Proposed Rulemaking included an increased 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 Rulemakings incentive for participation in an RTO by limiting this incentive for utilities thatjoin 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 FERCs incentives policy, or any further order on base ROE. A 50 basis point change in the FERC-allowed ROE would affectAmerens and Ameren Illinois annual net income by an estimated $12 million and $8 million, respectively, based on each companys 2022 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. If a given years 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 years 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 an order issued by the ICC in March 2021 Ameren Illinois expects to use the current IEIMA formula framework to establish annual customer rates effective through 2023, and reconcile the related revenue requirement for customer rates established for 2022 and 2023. As such, Ameren Illinois 2022 and 2023 revenues would reflect each years actual recoverable costs, year-end rate base, and a return atthe 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. For more information on the March 2021 ICC order, see Note 2 Rate and Regulatory Matters under Part II, Item 8, ofthe Form 10-K. By law, the decoupling 68
provisions extend beyond the end of existing performance-based formula ratemaking, which ensures that Ameren Illinois electric distribution revenues authorized in a regulatory rate review are not affected by changes in sales volumes.
e 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. An MYRP would allow 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 ICC-determined ROE for performance incentives and penalties. Ameren Illinois existing riders will remain effective whether it elects to file an MYRP or a traditional regulatory rate review. Additionally, electric distribution service revenues would continue to be decoupled from sales volumes under either election. Subject to a constructive outcome regarding the ICCs determination of performance metrics, Ameren Illinois anticipates filing an MYRP by mid-January 2023, with rates effective beginning in 2024. IfAmeren Illinois does not file an MYRP for rates effective beginning in 2024, its next opportunity to file an MYRP would be for rates effective beginning in 2028. For additional information regarding ratemaking under an MYRP, including details of the reconciliation cap, see Note 2 Rate and Regulatory Matters under Part II, Item 8, ofthe Form JO-K.
In 202J the ICC issued an order in Ameren Illinois annual update filing that approved a $58 million increase in Ameren Illinois electric distribution service rates beginning in January 2022. Ameren Illinois 2022 electric distribution service revenues will be based on its 2022 actual recoverable costs, 2022 year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average ofthe monthly yields of the 30-year United States Treasury bonds plus 580 basis points. As of June 30, 2022, Ameren Illinois expects its 2022 electric distribution year-end rate base to be $3.9 billion. The 2022 revenue requirement reconciliation adjustment will be collected from, or refunded to, customers in 2024. A 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 $J J million change in Amerens and Ameren Illinois annual net income, based on Ameren Illinois 2022 projected year-end rate base, including electric energy-efficiency investments. Ameren Illinois recognized ROE for the first six months of 2022 was based on an estimated annual average of the monthly yields of the 30-year United States Treasury bonds of 3.J0%.
In April 2022, Ameren Illinois filed its annual electric distribution service performance-based formula rate update with the ICC to be used for 2023 rates. In July 2022, Ameren Illinois filed a revised request seeking to increase its annual revenues for electric distribution service by
$84 million. In June 2022, the ICC staff submitted its calculation of the revenue requirement included in Ameren Illinois update filing, recommending a $60 million increase in Ameren Illinois electric distribution service rates. An ICC decision in this proceeding is required by December 2022, with new rates effective in January 2023. These rates will affect Ameren Illinois cash receipts during 2023, but will not affect electric distribution service revenues, which will be based on 2023 actual recoverable costs, 2023 year-end rate base, and a return at the applicable WACC as calculated under the Illinois performance-based formula ratemaking framework.
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 forAmeren 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 plan 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.
Ameren Missouris 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. During an outage, depending on the availability of its other generation sources and the market prices for power, Ameren Missouris purchased power costs may increase and the amount of excess power available for sale may decrease versus non-outage years. Changes in purchased power costs and excess power available for sale are included in the FAC, which results in limited impacts to earnings. In addition, Ameren Missouri may incur increased non-nuclear energy center maintenance costs in non-outage years.
Ameren Missouri continues to experience coal transportation disruptions in 2022, resulting in coal inventory levels below targeted levels at the Labadie, Rush Island, and Sioux energy centers as of the end of July 2022. Prolonged disruptions in the delivery of coal could have adverse effects on Ameren Missouris electric generation operations and could result in increased purchased power expense. Under the FAC, 95% of the variance in net energy costs, which includes purchased power expense, from the amount set in base rates is expected to be recovered. Further, the timing of payments for purchased power costs compared to the recovery through customer rates under the FAC could have adverse effects on Ameren and Ameren Missouris liquidity.
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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 ofthe Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. In June 2022, Ameren Missouri supplemented its filing with the district court by proposing reduced operations, mostly operating during peak demand times and emergencies until the energy center is retired. The March 31 2024 compliance date contained in the district courts September 201 9 remedy order remains in effect unless extended by the district court. In July 2022, in response to an Ameren Missouri request for a final, binding reliability assessment, the MISO designated the Rush Island Energy Center as a system support resource and concluded that certain mitigation measures, including transmission upgrades, should occur before the energy center is retired. The transmission upgrade projects have been approved by the MISO, and Ameren Missouri has started design and procurement activities necessary to complete the upgrades and expects to complete the upgrades by late 2025. The FERC will need to approve a system support resource agreement detailing the manner of continued operation of the Rush Island Energy Center, as well as a request from Ameren Missouri for recovery of non-energy costs under the related MISO tariff.
The agreement, ifapproved, would have a term of 12 months. The system support resource designation and the related agreement are subject to renewal and revision. Any difference between revenues and costs under the MISO tariff is expected to be included in the FAC.
The district court has the authority to determine the retirement date and operating parameters for the Rush Island Energy Center and is not bound by the MISO determination ofthe Rush Island Energy Center as a system support resource orthe FERCs approval. While the district court is under no deadline to issue a ruling modifying the remedy order, a decision is expected in the near term. For additional information on the NSR and Clean Air Act litigation, see Note 9 Commitments and Contingencies under Part I, Item I of this report. Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the planned acceleration of the retirement of the Rush Island Energy Center from 2039, the retirement year for the facility as reflected in the 2020 IRR In February 2022, the MoPSC issued an order directing the MoPSC staffto reviewAmeren Missouris planned accelerated retirement ofthe Rush Island Energy Center, including potential impacts on the reliability and cost ofAmeren Missouris service to its customers; Ameren Missouris plans to mitigate the customer impacts of the accelerated retirement; and the prudence ofAmeren Missouris actions and decisions with regard to the Rush Island Energy Center, which is expected to be addressed in the current electric service regulatory rate review, among other things. In April 2022, the MoPSC staff filed an initial report with the MoPSC in which the staff concluded early retirement ofthe Rush Island Energy Center may cause reliability concerns. The MoPSC staff is under no deadline to complete this review. As of December 31 2021 and June 30, 2022, Ameren and Ameren Missouri classified the remaining net book value of the Rush Island Energy Center as plant to be abandoned, net, within Property, Plant, and Equipment, Net on Amerens and Ameren Missouris balance sheets. 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.
The IETL established emission standards that became effective in September 2021 Ameren Missouris natural gas-fired energy centers in Illinois are subject to limits on emissions, including CO2 and NOx, equal to their unit-specific average emissions from 2018 through 2020, for any rolling twelve-month period beginning October 1 2021 through 2029. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure ofthe Venice Energy Center by 2029. The reductions could also limit the operations of Ameren Missouris other four natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to conditions in the IETL, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service as necessary. Ameren Missouri filed a 2022 Change to the 2020 IRP with the MoPSC in June 2022 to reflect, among other things, the updated scheduled retirement dates of the natural gas-fired energy centers located in the state of Illinois.
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 Missouris and Ameren Illinois service territories. The projected shortage resulted in higher capacity prices for June 2022 through May 2023, and the MISO indicated that the shortage may lead to temporary, controlled interruptions of service during the summer of 2022 to maintain system reliability.
We are observing inflationary pressures on the prices of 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 oftrackers, riders, and formula ratemaking, 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. Based on estimated power prices and customer demand, the capacity price set by the April 2022 MISO auction, and the amounts of energy and capacity hedged through IPA procurement events, Ameren Illinois estimates an increase to purchased power costs for calendar year 2022, compared to 2021 of ,
approximately $400 million. The actual increase 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. An increase to purchased power costs for calendar year 2023, compared to 2021 is also likely but Ameren Illinois cannot reasonably estimate the amount of the increase as additional energy and capacity contracts for 2023 will be entered into as a part of PA procurement events 70
later in 2022 and the first half of 2023, as well as pricing determined by the April 2023 MISO capacity auction. 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, based on the capacity price set by the April 2022 MISO auction, Ameren Missouri estimates increases to capacity revenues and purchased power costs for the calendar year 2022, compared to 2021 of approximately $375 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. An increase to capacity revenues and purchased power costs for calendar year 2023, compared to 2021 is 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 by the April 2023 MISO capacity auction. Capacity revenues and purchased power costs are a part ofthe 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.
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, economic impacts of the COVID-1 9 pandemic, 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 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 In February 2022, 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 2022. The plan is designed to upgrade Ameren Missouris electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $8.4 billion over the five-year period from 2022 through 2026, with expenditures largely recoverable under the PISA and the RESRAM.
a In June 2022, Ameren Missouri filed a notice of change in preferred resource plan with the MoPSC. The filing includes a 2022 Change to the 2020 IRP, which the MoPSC may review at its election. In connection with the change, Ameren revised its goals for reduction of carbon emissions. 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. Amerens goals include both direct emissions from operations, as well as electricity usage at Ameren buildings, 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 expanding renewable sources by adding 2,800 MWs of renewable generation by 2030, 400 MW5 of battery storage by 2035, and a total of 4,700 MW5 of renewable generation and 800 MWs of battery storage by 2040. These amounts include 350 MWs of solar generation projects discussed below. The change also includes 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 continued implementation of customer energy-efficiency programs, and the expectation that Ameren Missouri will seek and receive NRC approval for an extension of the operating license for the Callaway Energy Center beyond its current 2044 expiration date. Additionally, the change includes extending the retirement date of the coal-fired Sioux Energy Center from 2028 to 2030 in order to ensure reliability during the transition to clean energy generation, which is subject to the approval of a change in the assets depreciable life by the MoPSC in Ameren Missouris current electric service regulatory rate review, 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, 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 ofthe Venice natural gas-fired energy center to 2029, and retiring Ameren Missouris other natural gas-fired energy centers in Illinois by 2040. Ameren Missouris plan could be affected by, among other factors: Ameren Missouris ability to obtain certificates of convenience and necessity from the MoPSC, and any other required approvals for the addition of renewable resources, retirement of energy centers, and new or continued customer energy-efficiency programs; the ability to enter into build-transfer agreements for renewable generation and acquire that generation at a reasonable cost; the ability of 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 or government actions, among other things; changes in the scope and timing of projects; the availability of federal production and investment tax credits related to renewable energy and Ameren 71
Missouris ability to use such credits; the cost of wind, solar, and other renewable generation and storage technologies; the cost of natural gas or hydrogen CT technologies; changes in environmental regulations, including those related to CO2 and other greenhouse gas emissions; energy prices and demand; and Ameren Missouris ability to obtain necessary rights-of-way, easements, and transmission interconnection agreements at an acceptable cost and in a timely fashion. The next integrated resource plan is expected to be filed in September 2023.
o 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, including the repayment of existing debt. In connection with the planned accelerated retirement ofthe Rush Island Energy Center due to the NSR and Clean Air Act Litigation discussed above, 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. As such, Ameren Missouri did not request a change in the depreciation rates related to the Rush Island Energy Center in the electric regulatory rate review filed in August 2022.
In February 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a I 50-MW solar generation facility, which is expected to be located in southeastern Illinois and, if approved by the MoPSC, serve customers under Ameren Missouris Renewable Solutions Program. In June 2022, Ameren Missouri, through a subsidiary, entered into a build-transfer agreement to acquire, after construction, a 200-MW solar generation facility, which is expected to be located in central Missouri and support Ameren Missouris compliance with the state of Missouris requirement of achieving I 5% of retail sales from renewable energy sources, of which 2% must be derived from solar energy sources. The acquisitions are subject to certain conditions, including the issuance of certificates of convenience and necessity by the MoPSC, obtaining MISO transmission interconnection agreements, and approval by the FERC. In July 2022, Ameren Missouri filed for certificates of convenience and necessity with the MoPSC for both facilities and expects decisions by March 2023 and April 2023 for the 200-MW facility and the 150-MW facility, respectively. Depending on the timing of regulatory approvals and the impact of potential sourcing issues discussed below, the projects could be completed as early as the fourth quarter of 2024. Capital expenditures related to these facilities are not included in Amerens and Ameren Missouris expected capital investments discussed below.
Ameren Missouris 2022 Change to the 2020 IRP targets Ueaner and more diverse sources of energy generation, including solar generation.
While rights to acquire the solar facilities discussed above were secured through build-transfer 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 ofthese projects and other solar generation projects. The supply of solar panels to the United States was significantly disrupted as a result of an investigation initiated by the Department of Commerce in late March 2022, which could result in punitive tariffs on solar panels imported from four Southeast Asian countries. The investigation is in response to complaints of Chinese solar manufacturers shifting solar cells to these countries to avoid tariffs required on imports from China. The Department of Commerce is required to issue a preliminary determination within I 50 days of its initiation of an investigation, with final determination taking 300 days or more. Additionally, certain solar panels 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 was passed in December 2021 In June 2022, President Biden authorized the 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 panels imported from the four Southeast Asian countries under investigation by the Department of Commerce for 24 months in order to allow the United States access to a sufficient supply of solar panels to meet electricity generation needs while domestic manufacturing scales up. Any future tariffs or other outcomes resulting from the investigation by the Department of Commerce or actions by the United States Customs and Border Protection Agency could affect the cost and the availability of solar panels and the timing and amount ofAmeren Missouris estimated capital expenditures associated with solar generation investments.
Through 2026, 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 $18.0 billion (Ameren Missouri up to
$9.2 billion; Ameren Illinois up to $8.6 billion; ATXI up to $0.2 billion) of capital expenditures during the period from 2022 through 2026.
These planned investments are based on the assumption of continued constructive regulatory frameworks. Amerens and Ameren Missouris estimates exclude renewable generation investment opportunities of 800 MWs by 2026, which are included in Ameren Missouris 2022 Change to the 2020 IRP, and investment opportunities that may be approved by the MISO to address reliability concerns in connection with the planned accelerated retirement of the Rush Island Energy Center. These investment opportunities may be incremental to or partially replace other expenditures included in the 2022 through 2026 estimates above.
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 ofthe 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 MISOs cost estimate.
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The MISO is expected to initiate requests for proposals for the remaining projects included in the first tranche, which are expected to be awarded between mid-2023 and mid-2024. These investment opportunities may be incremental to or partially replace other expenditures included in the 2022 through 2026 estimates discussed above. In July 2022, a group of industrial customers filed a complaint with the FERC, challenging provisions ofa MISO tariffthat exclude regionaltransmission projects from the MISOs competitive bid process based on state laws related to the right offirst refusal, which provide an incumbent utility the rightto build, maintain, and own transmission lines located within its service territory. The complaint seeks to require MISO to revise its tariffto prohibit the application of state laws related to the right of first refusal in the MISCs 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 July 2022, an Illinois law prohibiting the states oversight of certain electric utilities choice of RTO membership ceased to be effective.
Given the change in law and the high prices resulting from MISOs 2022 capacity auction, the ICC issued an order requiring Ameren Illinois to perform a cost benefit study of continued participation in the MISO compared to participation in PJM Interconnection LLC, another RTO.
The cost benefit study will examine the impacts of participation in each RIO, 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 the study by July 2023. A 30-day comment period will follow. The ICC is under no obligation to issue an order in this matter.
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 AirAct Litigation discussed in Note 9 Commitments and Contingencies under Part I, Item I of this report, could result in significant increases in capital expenditures and operating costs. Regulations enacted by a prior federal administration can be reviewed and repealed, and replacement or alternative regulations can be proposed or adopted by the current federal administration including the EPA. The ultimate implementation of any of these 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 ofAmeren Missouris coal and natural gas-fired energy centers. Ameren Missouris capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances as well as regulatory lag.
The cost ofAmeren 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.
Amerens and Ameren Missouris 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 $2.3 billion of credit through December 2025, subject to a 364-day repayment term forAmeren Missouri and Ameren Illinois, with the option to seek incremental commitments to increase the cumulative credit provided to $2.7 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 CreditAgreements. By the end of 2022, $55 million, $400 million, and $50 million of long-term debt obligations are due to mature at Ameren Missouri, Ameren Illinois, and ATXI, respectively. Ameren, Ameren Missouri, and Ameren Illinois believe that their liquidity is adequate given their expected operating cash flows, capital expenditures, and financing plans. To date, the Ameren Companies have been able to access the capital 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 DRPIus and employee benefit plans and expects to continue to do so through at least 2026. Ameren expects these issuances to provide equity of about $100 million annually. In addition, in 2021 Ameren ,
established an ATM program under which Ameren may offer and sell from time to time up to $750 million of its common stock, which includes the ability to enter into forward sales agreements, subject to market conditions and other factors. Ameren has entered into multiple forward sale agreements under the ATM program with various counterparties relating to 5.8 million shares of common stock. As of June 30, 2022, Ameren could have settled the forward sale agreements with physical delivery of 5.6 million shares of common stock to the respective counterparties in exchange for cash of $500 million. As of June 30, 2022, Ameren had approximately $90 million of common stock available under the ATM program, which takes into account the forward sale agreements in effect as of June 30, 2022. For additional information regarding outstanding forward sale agreements, including settlement dates, see Note 4 Long-Term Debt and Liquidity under Part I, Item I, of this report. Ameren expects to settle approximately $300 million of the forward sale agreements by December 31 2022. Ameren plans to issue approximately $300 million of equity each year from 2022 to 2026 in addition to issuances under the DRPIus and employee benefit plans. Ameren expects its equity to total capitalization ratio to be approximately 45% through December 31 2026, 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).
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. As ofJune 30, 2022, Ameren had $146 miNion in tax benefits from federal and state income tax credit carryforwards and $38 million in tax benefits from federal and state net operating loss carryforwards, which will be utilized in future periods. Ameren expects federal income tax payments at the required minimum levels from 2022 to 2026 resulting from the anticipated use of existing production tax credits generated by Ameren Missouris High Prairie Renewable and Atchison Renewable energy centers, existing tax net operating losses, tax credit carryforwards, tax overpayments, and outstanding refunds.
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 Amerens 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 I 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 I 0-K, except as discussed below. See Item ZA under Part II of the Form I 0-K for a more detailed discussion of our market risk.
Ameren Missouri has an immaterial amount of enriched uranium intended to be utilized later this decade that is sourced from a Russian supplier and could become subject to future sanctions. Ameren Missouri is reviewing options to reduce its exposure to Russian-sourced supplies. Ameren Missouri has inventories and supply contracts from non-Russian suppliers sufficient to meet all of its uranium (concentrate and hexafluoride), conversion, and enrichment requirements at least through the 2026 refueling of the Callaway Energy Center.
ITEM 4. CONTROLS AND PROCEDURES.
(a) Evaluation of Disclosure Controls and Procedures As of June 30, 2022, 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 registrants disclosure controls and procedures (as defined in Rules I 3a-1 5(e) and I 5d-1 5(e) of the Exchange Act). Based on those evaluations, as of June 30, 2022, 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 registrants reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SECs rules and forms and such information is accumulated and communicated to its management, including its principal executive officer and its principal financial officer, to allow timely decisions regarding required disclosure.
(b) Changes in Internal Controls over Financial Reporting There has been no change in any of the Ameren Companies internal control over financial reporting during their most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, each of their internal control over financial reporting.
PART II. OTHER INFORMATION ITEM 1. LEGAL PROCEEDINGS.
We are involved in legal and administrative proceedings before various courts and agencies with respect to matters that arise in the ordinary course of business, some of which involve substantial amounts of money. We believe that the final disposition of these proceedings, except as otherwise disclosed in this report, will not have a material adverse effect on our results of operations, financial position, or liquidity. Risk of loss is mitigated, in some cases, by insurance or contractual or statutory indemnification. We believe that we have established appropriate reserves for potential losses. For additional information on material legal and administrative proceedings, see Note 2 Rate and Regulatory Mattis.
Note 9 Commitments and Contingencies, and Note 10 Callaway Energy Center, under Part I, Item 1, ofthis report. Pursuantto 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 IA. RISK FACTORS.
There have been no material changes to the risk factors disclosed in Part I, Item IA, Risk Factors in the Form 10-K.
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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 April 1 2022, to June 30, 2022.
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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 Degnation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to:
Material Contracts 10.1 Ameren Companies *Ameren Copocation O22 Omnibus Incentive Compensation Plan Exhibit 991, File No. 333-264876 Rule 13a-14(a) I 15d-14(a) Certifications Ameren Rule 13a-14()/15d-14() Certification of Principal Executive Officer ofAmeren 31.2 Ameren Rule 13a-14()115d-14()CertificationofPrincipal FinancialOfficerofAmeren 31 .3 Ameren Missouri Rule 13a-14(8)/15d-14(a) Certification of Principal Executive Officer of Ameren Missouri 31.4 Ameren Missouri Rule 13a-14)I15d-14() Certification of Principal Financial Officer of Ameren Missouri 31.5 Ameren Illinois Rui3a-14(i5d-14()ertiflcationoffrincipaLExecutiveOfficerofAmeren Illinois 31.6 Ameren Illinois Rule 13a-14(J/15d-14()Certificabon of Principal Financial Officer ofAmeren 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 1 350 Certification of Principal Executive Officer and Principal Financial Officer ofAmeren Missouri 32.3 Ameren Illinois Section 1350 Certification of Principal Executive Officer and Principal Financial cer oAmeren illinois Interactive Data Files 1O1.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 I 01 .SCH Ameren Companies Inline XBRL Taxonomy Extension Schema Document o1cALAmerenCornparesinhnexBRLTaXonExtensnCalculation LrnkbaseDocument 101 LAB Ameren Companies Inline XBRL Taxonomy Extension Label Linkbase Document i_1 PRE Ameren Companies lnlineXBRLTaxonoytension Presentation Linkbase Document 1O1.DEF Ameren Companies Inline XBRL Taxonomy Extension Definition Document 104 Ameren Companies Covet Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit I 01)
The file number references fortheAmeren 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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