Ameren
Annual Report 2021

Plain-text annual report

Transforming For Our Future 202 1 ANNUAL R EPORT Financial Highlights AMEREN CONSOLIDATED 2021 2020 2019 (In millions, except per share amounts and as noted) RESULTS OF OPERATIONS Operating revenues Operating expenses Operating income Net income attributable to Ameren common shareholders COMMON STOCK DATA Earnings per diluted share Dividends per common share Dividend yield (year-end) Market price per common share (year-end closing) Weighted-average common shares outstanding – diluted Weighted-average common shares outstanding – basic Total market value of common shares (year-end) Book value per common share (year-end) BAL ANCE SHEET DATA Property, plant and equipment, net Total assets Long-term debt obligations, including current maturities Total equity $ $ $ $ $ $ $ $ $ $ $ $ $ OPERATING DATA Electric sales (kilowatt-hours) Natural gas sales (dekatherms in thousands) Electric customers Natural gas customers $ $ $ $ $ $ $ $ $ $ $ $ $ 6,394 5,061 1,333 990 3.84 2.20 2.5 % 89.01 257.6 256.3 22,938 37.64 29,261 35,735 13,067 9,829 73,088 193,681 2.4 0.9 5,794 4,494 1,300 871 3.50 2.00 2.6 % 78.06 248.7 247.0 19,773 35.29 26,807 32,030 11,086 9,080 71,907 193,761 2.4 0.9 $ $ $ $ $ $ $ $ $ $ $ $ $ 5,910 4,643 1,267 828 3.35 1.92 2.6 % 76.80 247.1 245.6 18,908 32.73 24,376 28,933 9,357 8,201 73,629 205,899 2.4 0.9 1 Executive Chairman To Our Fellow Shareholders: President and CEO In the fall of 2021, as part of our robust succession planning process, Ameren announced a new forward-thinking leadership structure with the creation of an executive chairman position, effective Jan. 1, 2022. The executive chairman role will focus on key strategic matters impacting the company, including the energy and economic policies that are critical to the exciting transformation taking place in our industry, while the president and chief executive officer will continue to be responsible for strategy development and day-to-day execution across the entire enterprise. Together, we will continue to support our mission — To Power the Quality of Life for millions of electric and natural gas customers throughout Missouri and Illinois, all while continuing to deliver strong results for shareholders. We and the Ameren team remain passionate about creating value for our customers, shareholders and communities by executing on our vision to Lead the Way to a Sustainable Energy Future by achieving transformative environmental goals, delivering meaningful social impact, continuing robust corporate governance and delivering strong sustainable growth. 2021 AMEREN ANNUAL REPORTAS WE EMBARK ON THIS LEADERSHIP TRANSITION, we do so keeping our customers at the center of everything we do to deliver safe, reliable, cleaner and affordable energy. As testament to our focus on customers, we are proud to report that an industry-leading consumer sentiment survey recently ranked Ameren Illinois first and Ameren Missouri third in residential customer satisfaction among our electric peers in the Midwest. We deeply appreciate the extraordinary efforts made by our co-workers, day in and day out and throughout the COVID-19 pandemic, to safely execute our strategy and deliver for our customers and the communities we serve. We have and will continue to positively impact customers and communities through environmental stewardship and are making progress toward our goal of net-zero carbon emissions by 2050. We are also supporting and partnering with local nonprofits and organizations that create meaningful, long- lasting social impact. We are operating our company with a commitment to the highest levels of ethical business practices and strong corporate governance. And we are committed to continuous improvement with an unwavering focus on providing ever- growing value to our customers and to you, our shareholders. TRANSFORMATIVE ENVIRONMENTAL GOALS: Committed to Net-Zero Emissions In 2020, in connection with Ameren Missouri’s Integrated Resource Plan filing with the Missouri Public Service Commission, we established a goal of achieving net-zero carbon emissions by 2050 across all operations. To meet our goals, we’ve made significant investments in renewable energy. In 2021, we saw the first year of operation for our two large-scale wind facilities in northern Missouri, which added 700 megawatts of generation through an approximately $1 billion investment. In addition, we are making significant electric and natural gas investments in other innovative technologies that are transforming the grid, making it cleaner, safer, more reliable, resilient and secure. In addition, our Ameren natural gas distri- bution systems are comprised almost entirely of polyethylene and protective-coated steel pipelines, with the remaining few miles of unprotected, leak-prone steel pipe replaced in 2021, helping to further reduce methane emissions from our operations. Greenhouse gas reductions will be amplified in Missouri with the planned retirement of our Meramec Energy Center 0NET 5 0 2 Y B ZERO 3 later this year and the expected accelerated closure of the Rush Island Energy Center. In addition, the expansion of solar energy programs offers additional opportunities to grow renewable energy for our customers in both Missouri and Illinois. year-round community outreach and educational initiatives. We once again hosted a DE&I Leadership Summit for the Ameren team and community leaders featuring local and national speakers, to provide a unique learning and engage- ment experience. 7 1 0 2 E C N S I invested more We have than $3 billion since 2017 in transmission the infrastructure, strengthening our backbone and of grid enabling greater levels of clean renewable energy to be accessed. Throughout 2021, we led efforts to revolutionize transportation through the expansion of electric vehicle charging stations across the Midwest, supporting our own initiatives and national efforts led by the Edison Electric Institute (EEI) and others. And we further demonstrated our commitment to a sustain- able energy future by naming our first chief sustainability officer to help guide these continued efforts. SOCIAL IMPACT: Promoting Diversity, Equity and Inclusion in Our Business and Communities We are committed to diversity, equity and inclusion (DE&I) at our company and in our communities. Though this strong commitment starts at the highest levels of leadership, we expect the entire Ameren team to live our core values, which include respect, teamwork and DE&I. initiatives Throughout 2021, we enhanced our DE&I through successful programs, including our Employee Resource Groups. These multicultural groups are led by our co-workers who support our business goals through Our industry-recognized supplier diversity program continued to drive inclusive economic growth opportunities for minority- owned, women-owned and veteran-owned businesses through diverse supplier spend that totaled approximately $900 million in 2021. In addition, we have once again partnered with the University of Missouri–St. Louis Diversity, Equity & Inclusion Accelerator program to put underrepresented entrepreneurs at the center of a purpose-driven initiative, to fuel their creative business models and address the region’s economic disparities. These efforts and more have garnered Ameren several national recognitions, including being named by DiversityInc as the nation’s Top Utility for DE&I in 2021; the EEI Excellence Award for contributions to diverse supplier inclusion and development; as well as being named a Best Place to Work for Disability Inclusion by the Disability Equality Index. Investing in Our Communities The pandemic has had a long-lasting impact on the communities we serve. So many families find themselves in unforeseen financial and personal situations. At Ameren, we’ve been working since the onset of the pandemic to provide multiple avenues of support for those struggling economically. Our ongoing efforts include the use of flexible payment plans to assist those facing financial hardship. In addition, we’ve worked with customers to connect them to millions of dollars A few Awards and Recognitions earned by Ameren during 2021: 2021 AMEREN ANNUAL REPORT3B$ 4 OUR VALUES in energy assistance from state and federal sources and expanded unique company-funded programs, such as Clean Slate in Missouri and Fresh Start in Illinois, to assist those who may not qualify for other assistance programs. We continue to build on our long history of philanthropic support. In addition to supporting donations targeting energy and other assistance programs, the company donated more than $10 million in 2021 to nonprofits focused on addressing critical human needs, advancing wellness in our communities, improving educational opportunities for children and job readiness for young adults, encouraging revitalization efforts to grow the regional economy, and much more. We as a team also contributed our time and talents throughout the year to various volunteer initiatives. These included distributing school supplies to educators from underserved school districts and giving out energy-efficient air conditioners to seniors and people with disabilities to help them stay safe and cool during the summer. Ameren remains focused on serving our communities and giving back to our neighbors in times of need. GOVERNANCE Our steadfast commitment to our corporate values — including integrity — means that we always strive to conduct our business with the highest ethical standards. This is key to our long-range success, and this tone is set at the top by our experienced, engaged board of directors and senior leadership. This diverse group of leaders oversees the pursuit of our strategic objectives and sets a high bar for performance. SAFETY AND SECURITY NEVER COMPROMISE INTEGRITY DO THE RIGHT THING RESPECT VALUE OTHERS DIVERSITY, EQUITY AND INCLUSION BE COURAGEOUS COMMITMENT TO EXCELLENCE BRING YOUR BEST TEAMWORK WORK TOGETHER ACCOUNTABILITY OWN YOUR ACTIONS AND INACTIONS STEWARDSHIP LEAVE IT BETTER STRATEGY TRANSFORMING FOR OUR FUTUREPhoto taken pre-COVID-19. VALUES 5 tied To ensure ongoing progress, our board of directors has established executive compensation metrics to sustainable long-term earnings and dividend growth, operating performance, safety, DE&I and progress toward clean energy goals. These metrics are reinforced by empowering and encouraging all Ameren co-workers to speak up and engage on issues impacting the company, our customers and the communities we serve. Results are important, but more important is how we get them. Guided by an enduring strategy, lasting core values, including a promise to always do business the right way, and a continuous improvement mindset — we will achieve even higher heights together. Delivering SUSTAINABLE GROWTH Our long-term sustainable growth strategy is bringing value to our customers and providing strong results for our shareholders. Ameren is effectively managing billions of dollars of infra- structure investments, working with stakeholders to put in place constructive energy policies and achieve constructive regulatory outcomes. This includes the recent Illinois clean energy and Missouri securitization bills passed in their respective states that we expect will have a positive impact on future investments for the benefit of our customers. Our infrastructure investments, coupled with our disciplined cost management, are delivering results for our customers and shareholders. Our customers experience electric rates among the lowest in the country — well below the national average — and reliability that has improved 12% since 2013. Our weather-normalized earnings per share grew nearly 8% over 2020 results. Since the transition to an all rate-regulated business in 2013, Ameren has delivered weather-normalized core earnings per share growth of 84%, or an approximate 8% compound annual growth rate. Reflecting the confidence of Ameren’s board of directors, we recently announced a more than 7% increase to our dividend, further demonstrating WE WILL INVEST AND OPERATE IN A MANNER CONSISTENT WITH EXISTING REGULATORY FRAMEWORKS, ADVOCATE FOR RESPONSIBLE POLICIES AND CAPITALIZE ON INVESTMENT OPPORTUNITIES TO DELIVER SUPERIOR CUSTOMER AND SHAREHOLDER VALUE. AMEREN’S STRATEGY 2021 AMEREN ANNUAL REPORT 6 our successful growth strategy — the ninth consecutive year increasing our dividend. For a second consecutive year, Ameren received the total shareholder return Index Award from the EEI as the top-ranking mid-cap company in our industry. This recognition signals successful execution of our strategy to deliver superior customer and shareholder value. Over the next five years, we plan to execute approxi- mately $17 billion in capital projects to enhance the reliability and resiliency of our energy grid, transition to a cleaner and more diverse generation portfolio, and implement new digital technologies and cybersecurity tools. These investments are expected to deliver strong com- pound annual earnings per share growth of 6% to 8% from 2022–2026 (using our 2022 earnings per diluted share guidance range midpoint of $4.05 as the base).* Looking investment ahead, we see customer value-enhancing opportunities for Ameren totaling more than $45 billion over the next decade to achieve our clean energy trans- formation. These factors, when coupled with a strong dividend, position Ameren to continue delivering sustainable and superior long-term value. CLOSING Our relentless focus on our customers and the com- munities we serve has driven our ability to deliver ever-increasing value to them in terms of reliability, cleaner energy, affordability and community service, even during the challenging period we have been operating under for more than two years due to the 1.0 0.9 0.8 0.7 0.6 0.5 IMPROVED RELIABILITY 0.89 BETTER 0.78 2021 As measured by the System Average Interruption Frequency Index (SAIFI). Represents the average of Ameren Illinois and Ameren Missouri. Y C N E U Q E R F E G A T U O r a e y r e p r e m o t s u c r e p AFFORDABLE RATES 13.62 12.89 9.70 10.06 I R U O S S I M N E R E M A S I O N I L L I N E R E M A E G A R E V A T S E W D M I E G A R E V A . . S U 15 12 9 6 3 0 Ameren Illinois’ residential rates are 22% lower than the Midwest Average and 26% lower than the U.S. Average. Ameren Missouri’s residential rates are 25% lower than the Midwest Average and 29% lower than the U.S. Average. Average Residential Electric Prices are provided by Edison Electric Institute, “Typical Bills and Average Rates Report” for the 12 months ended June 30, 2021. *Effective as of Feb. 18, 2022, Earnings Conference Call. TRANSFORMING FOR OUR FUTURE2013 12% $4.15 $3.75 $3.35 $2.95 $2.55 $2.15 $1.75 WEATHER-NORMALIZED CORE EARNINGS PER DILUTED SHARE 84% SINCE 2013 2 8 3 $ . 4 5 . 3 $ 2 3 3 $ . 5 0 3 $ . 8 8 . 2 $ 9 5 . 2 $ 8 5 2 $ . 7 3 2 $ . 8 0 . 2 $ 3 1 0 2 4 1 0 2 5 1 0 2 6 1 0 2 7 1 0 2 8 1 0 2 9 1 0 2 0 2 0 2 1 2 0 2 See inside back cover for GAAP to core and weather-normalized earnings per share reconciliations. pandemic. Moreover, execution of our strategy will continue to deliver on a strong long-term sustainability value proposition. For us, being able to lead such a dedicated and committed Ameren team is an honor and humbling responsibility. As we look ahead, central to our success will be keeping our customers at the center of our strategy and our focus on continuous improvement, including: > Our ongoing commitment to Ameren’s strategy and organizational values. > Continuing to enhance customer satisfaction. > Investing in a smarter, more reliable and resilient grid, as well as in cleaner energy resources. > Driving a clean energy transformation in a responsible fashion. > Managing costs to continue keeping customers’ electric and natural gas bills affordable. > Advocating for constructive energy policies to support investment and benefits to our customers. > Supporting regional economic development and electrification. 7 $2.27 $2.16 $2.05 $1.94 $1.83 $1.72 $1.61 $1.50 DIVIDENDS PAID PER SHARE $2.20 38% SINCE 2013 $2.00 $1.92 $1.85 $1.78 $1.72 $1.66 $1.60 $1.61 2013 2014 2015 2016 2017 2018 2019 2020 2021 Unrounded dividends 2015–2018 are $1.655, $1.715, $1.7775 and $1.8475. TOTAL SHAREHOLDER RETURN: 2013–2021 AMEREN 218% PHILADELPHIA UTILITY INDEX 171% S&P 500 UTILITY INDEX 149% 120% 140% 160% 180% 200% 220% Eight-Year Total Cumulative Shareholder Return, Dec. 31, 2013 through Dec. 31, 2021. WE BELIEVE THAT IF WE DELIVER for our customers and keep them at the center of every- thing we do, we’ll deliver for you, our shareholders. That’s what we’ve been able to do for many years and will continue to do as we transform for our future together. It’s exciting to work with such a dedicated team that is committed to our mission, To Power the Quality of Life, while successfully executing our strategy and delivering tremendous value to our customers, communities and shareholders. And even more exciting is that this team is well positioned to continue doing so. Thank you for your continued support of Ameren. WARNER L. BAXTER Executive Chairman Ameren Corporation MARTIN J. LYONS JR. President and CEO Ameren Corporation March 1, 2022 *Effective as of Feb. 18, 2022, Earnings Conference Call. 2021 AMEREN ANNUAL REPORT8 Executive Leadership Team 9. MARY P. HEGER Senior Vice President, Customer Experience, Ameren Illinois 10. MARK C. LINDGREN Senior Vice President, Corporate Communications and Chief Human Resources Officer, Ameren Services 11. CHONDA J. NWAMU Senior Vice President, General Counsel and Secretary, Ameren Corporation 1. WARNER L. BAXTER Executive Chairman, Ameren Corporation 2. MARTIN J. LYONS JR. President and Chief Executive Officer, Ameren Corporation 3. RICHARD J. MARK Chairman and President, Ameren Illinois 4. MARK C. BIRK Chairman and President, Ameren Missouri 5. SHAWN E. SCHUKAR Chairman and President, Ameren Transmission Company of Illinois 6. MICHAEL L. MOEHN Executive Vice President and Chief Financial Officer, Ameren Corporation; Chairman and President, Ameren Services 7. BHAVANI AMIRTHALINGAM Senior Vice President and Chief Digital Information Officer, Ameren Services 8. FADI M. DIYA Senior Vice President and Chief Nuclear Officer, Ameren Missouri 2 1 4 8 3 7 5 6 9 10 11 TRANSFORMING FOR OUR FUTUREAmeren Corporation & Subsidiaries Officers 9 KEVIN D. ANDERS Vice President, Operations and Technical Services, Ameren Missouri RYAN M. ARNOLD Vice President, Division Operations, Ameren Missouri AJAY K. ARORA Vice President and Chief Renewable Development Officer, Ameren Missouri STEPHANIE P. BANKER Vice President, Nuclear Engineering and Support, Ameren Missouri KRISTA G. BAUER Vice President, Human Resources, Ameren Services JAMES C. BLESSING Vice President, Regulatory Policy and Energy Supply, Ameren Illinois ROBERT L. CHILDS JR. Vice President, Digital Products, Ameren Services BARRY L. COX Nuclear Site Vice President, Ameren Missouri KEVIN A. DEGRAW Vice President, Nuclear Corporate Oversight, Ameren Services MATTHEW A. FORCK Vice President, Federal Legislative Affairs, Ameren Services MARK J. FRONMULLER Senior Vice President, Strategy, Innovation, Sustainability and Risk, Ameren Services PARDEEP S. GILL Vice President, Supply Chain and Chief Procurement Officer, Ameren Services JERRY L. GRANT Vice President, Financial Services, Ameren Services MICHAEL K. GREEN Vice President and Chief Information Security Officer, Ameren Services SHARON HARVEY DAVIS Vice President, Diversity, Equity and Inclusion and Chief Diversity Officer, Ameren Services GEORGE T. JUSTICE Vice President, Electric Operations and Technical Services, Ameren Illinois ROBIN M. KIES Vice President, Financial Services and Performance Management, Ameren Illinois ERIC M. KOZAK Vice President, Gas Operations and Distribution, Ameren Illinois TIMOTHY E. LAFSER Vice President, Power Operations, Ameren Missouri STEPHEN C. LEE Vice President and Deputy General Counsel, Ameren Services DAVID R. LOESCH Vice President and Controller, Ameren Corporation GERALYNN M. LORD Vice President, Corporate Communications, Ameren Services RYAN J. MARTIN Vice President, Internal Audit and Chief Audit Executive, Ameren Services GWEN G. MIZELL Vice President, Innovation and Chief Sustainability Officer, Ameren Services MICHAEL G. MUELLER Vice President, Economic Development, Ameren Illinois TARA K. OGLESBY Vice President, Customer Experience, Ameren Missouri TIMOTHY E. REAGAN Vice President, Corporate Security and Crisis Management, Ameren Services JOHN D. RHEA Vice President and Chief Ethics and Compliance Officer, Ameren Services DAVID ROSENBERG Vice President, Digital Technology and Operations, Ameren Services DARRYL T. SAGEL Vice President and Treasurer, Ameren Corporation ERIC V. SEIDLER Senior Vice President, Corporate Safety, Security and Operations Oversight, Ameren Services THERESA A. SHAW Senior Vice President, Finance and Chief Accounting Officer, Ameren Corporation JAMIE SIMLER Vice President, Federal Regulatory Affairs, Ameren Services PATRICK E. SMITH Vice President, Economic, Community and Business Development, Ameren Missouri BRUCE A. STEINKE Chief Transformation Officer, Ameren Services HAROON TAQI Vice President, Digital Portfolio, Architecture and Governance, Ameren Services DAVID N. WAKEMAN Senior Vice President, Operations and Technical Services, Ameren Illinois DENNIS W. WEISENBORN Vice President, Corporate Safety, Ameren Services LUKE N. WOLLIN Vice President, Engineering and Construction, Ameren Services WARREN T. WOOD Vice President, Regulatory and Legislative Affairs, Ameren Missouri PLEA SE JOIN U S FO R T HE ANNUAL MEETI NG OF SHAREHO LDE RS MAY 12 ONLIN E AT 10 A.M. CD T The officers also include the Ameren Executive Leadership Team on Page 8. The officer and Board of Directors listings are as of Feb. 22, 2022. 2021 AMEREN ANNUAL REPORT10 Ameren’s Board of Directors 1. WARNER L. BAXTER Executive Chairman, Ameren Corporation 2. CYNTHIA J. BRINKLEY Retired Chief Administrative and Markets Officer, Centene Corporation Human Resources Committee; Nuclear, Operations and Environmental Sustainability Committee 3. CATHERINE S. BRUNE Retired President, Allstate Protection Eastern Territory of Allstate Insurance Company Nominating and Corporate Governance Committee (Chair); Audit and Risk Committee 4. J. EDWARD COLEMAN Retired Executive Chairman, CIOX Health Audit and Risk Committee (Chair); Finance Committee 5. WARD H. DICKSON Retired Executive Vice President and Chief Financial Officer, WestRock Company Audit and Risk Committee; Finance Committee (Chair) 6. NOELLE K. EDER Executive Vice President and Global Chief Information Officer, Cigna Corporation Audit and Risk Committee; Nominating and Corporate Governance Committee 7. ELLEN M. FITZSIMMONS Chief Legal Officer and Head of Public Affairs, Truist Financial Corporation Finance Committee; Nuclear, Operations and Environmental Sustainability Committee 11. JAMES C. JOHNSON Retired General Counsel, Loop Capital Markets LLC Human Resources Committee (Chair); Nominating and Corporate Governance Committee 12. STEVEN H. LIPSTEIN Retired President and Chief Executive Officer, BJC HealthCare Human Resources Committee; Nominating and Corporate Governance Committee 8. RAFAEL FLORES Retired Senior Vice President and Chief Nuclear Officer, Luminant Corporation Nominating and Corporate Governance Committee; Nuclear, Operations and Environmental Sustainability Committee 9. RICHARD J. HARSHMAN Retired Executive Chairman, President and Chief Executive Officer, Allegheny Technologies Incorporated Lead Director; Human Resources Committee; Nuclear, Operations and Environmental Sustainability Committee (Chair) 13. MARTIN J. LYONS JR. President and Chief Executive Officer, Ameren Corporation 14. LEO S. MACKAY JR. Senior Vice President, Ethics and Enterprise Assurance, Lockheed Martin Corporation Audit and Risk Committee; Nuclear, Operations and Environmental Sustainability Committee 1 4 3 2 8 10. CRAIG S. IVEY Retired President, Consolidated Edison Company of New York Inc. Finance Committee; Nuclear, Operations and Environmental Sustainability Committee 6 7 11 12 5 10 14 9 13 TRANSFORMING FOR OUR FUTUREUNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-K ☒ Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the fiscal year ended December 31, 2021 OR ☐ Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the transition period from           to Commission File Number 1-14756 1-2967 1-3672 Exact name of registrant as specified in its charter; State of Incorporation; Address and Telephone Number Ameren Corporation (Missouri Corporation) 1901 Chouteau Avenue St. Louis, Missouri 63103 (314) 621-3222 Union Electric Company (Missouri Corporation) 1901 Chouteau Avenue St. Louis, Missouri 63103 (314) 621-3222 Ameren Illinois Company (Illinois Corporation) 10 Executive Drive Collinsville, Illinois 62234 (618) 343-8150 IRS Employer Identification No. 43-1723446 43-0559760 37-0211380 Securities Registered Pursuant to Section 12(b) of the Act: The following security is registered pursuant to Section 12(b) of the Securities Exchange Act of 1934 and is listed on the New York Stock Exchange: Title of each class Common Stock, $0.01 par value per share Trading Symbol(s) AEE Name of each exchange on which registered New York Stock Exchange Securities Registered Pursuant to Section 12(g) of the Act: Registrant Union Electric Company Title of each class Preferred Stock, cumulative, no par value, stated value $100 per share Ameren Illinois Company Preferred Stock, cumulative, $100 par value Indicate by checkmark if each registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Ameren Corporation Union Electric Company Ameren Illinois Company Yes Yes Yes ☒ ☒ ☒ No No No Indicate by checkmark if each registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Ameren Corporation Union Electric Company Ameren Illinois Company Yes Yes Yes ☐ ☐ ☐ No No No Indicate by checkmark whether the registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Ameren Corporation Union Electric Company Ameren Illinois Company Yes Yes Yes ☒ ☒ ☒ No No No ☐ ☐ ☐ ☒ ☒ ☒ ☐ ☐ ☐ Indicate by checkmark 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 Union Electric Company Ameren Illinois Company Yes Yes Yes ☒ ☒ ☒ No No No ☐ ☐ ☐ Indicate by checkmark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 of the Exchange Act. Ameren Corporation Large accelerated filer ☒ Accelerated filer Union Electric Company Large accelerated filer ☐ Accelerated filer Ameren Illinois Company Large accelerated filer ☐ Accelerated filer Smaller reporting company Smaller reporting company Smaller reporting company ☐ Non-accelerated filer ☐ Emerging growth company ☐ Non-accelerated filer ☐ Emerging growth company ☐ Non-accelerated filer ☐ Emerging growth company ☐ ☐ ☒ ☐ ☒ ☐ If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. Ameren Corporation Union Electric Company Ameren Illinois Company Indicate by check mark whether each registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. Ameren Corporation Union Electric Company Ameren Illinois Company Indicate by checkmark whether each registrant is a shell company (as defined in Rule 12b-2 of the Act). Ameren Corporation Union Electric Company Ameren Illinois Company Yes Yes Yes ☐ ☐ ☐ No No No ☐ ☐ ☐ ☒ ☐ ☐ ☒ ☒ ☒ As of June 30, 2021, the aggregate market value of Ameren Corporation’s common stock, $0.01 par value, (based upon the closing price of the common stock on the New York Stock Exchange on June 30, 2021) held by nonaffiliates was $20,481,306,104. All of the shares of common stock of the other registrants were held by Ameren Corporation as of June 30, 2021. The number of shares outstanding of each registrant’s classes of common stock as of January 31, 2022, were as follows: Registrant Ameren Corporation Title of each class of common stock Common stock, $0.01 par value per share Union Electric Company Common stock, $5 par value per share, held by Ameren Corporation Ameren Illinois Company Common stock, no par value, held by Ameren Corporation DOCUMENTS INCORPORATED BY REFERENCE Shares 257,724,783 102,123,834 25,452,373 Portions of the definitive proxy statement of Ameren Corporation and portions of the definitive information statements of Union Electric Company and Ameren Illinois Company for the 2022 annual meetings of shareholders are incorporated by reference into Part III of this Form 10-K. This combined Form 10-K is separately filed by Ameren Corporation, Union Electric Company, and Ameren Illinois Company. Each registrant hereto is filing on its own behalf all of the information contained in this annual 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. (This page has been left blank intentionally.) TABLE OF CONTENTS GLOSSARY OF TERMS AND ABBREVIATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . FORWARD-LOOKING STATEMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PART I Item 1. Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Business Segments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rates and Regulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Supply of Electric Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power Generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Renewable Energy and Zero Emission Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Customer Energy-Efficiency Programs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural Gas Supply for Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Human Capital Management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . The COVID-19 Pandemic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industry Issues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating Statistics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Available Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Risk Factors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 1A. Unresolved Staff Comments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 1B. Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 2. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 3. Item 4. Mine Safety Disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Information about Our Executive Officers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PART II Item 5. Item 6. Item 7. Item 7A. Item 8. Market for Registrants’ Common Equity, Related Stockholder Matters, and Issuer Purchase of Equity Securities . . . . . . (Reserved) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Management’s Discussion and Analysis of Financial Condition and Results of Operations . . . . . . . . . . . . . . . . . . . . . . . Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Results of Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liquidity and Capital Resources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Outlook . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounting Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Union Electric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 1. Summary of Significant Accounting Policies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 2. Rate and Regulatory Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 3. Property, Plant, and Equipment, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 4. Short-term Debt and Liquidity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 5. Long-term Debt and Equity Financings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 6. Other Income, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 7. Derivative Financial Instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 8. Fair Value Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Page 1 4 6 6 7 7 9 9 10 11 12 13 13 15 16 18 20 20 31 32 33 33 34 36 37 37 38 42 57 67 73 73 76 80 86 90 94 98 103 114 115 118 124 125 127 Note 9. Callaway Energy Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 10. Retirement Benefits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 11. Stock-based Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 12. Income Taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 13. Related-party Transactions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 14. Commitments and Contingencies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 15. Supplemental Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note 16. Segment Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Changes in and Disagreements with Accountants on Accounting and Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Disclosure Regarding Foreign Jurisdictions that Prevent Inspections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Directors, Executive Officers, and Corporate Governance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters . . . . . . . . . . . . . . Certain Relationships and Related Transactions and Director Independence . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Principal Accountant Fees and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 9. Item 9A. Item 9B. Item 9C. PART III Item 10. Item 11. Item 12. Item 13. Item 14. PART IV Exhibits and Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 15. Form 10-K Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 16. EXHIBIT INDEX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131 134 140 141 144 147 151 154 159 159 159 159 159 160 160 161 161 162 167 168 176 This report contains “forward-looking” statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements should be read with the cautionary statements and important factors under the heading “Forward- looking Statements.” Forward-looking statements are all statements other than statements of historical fact, including those statements that are identified by the use of the words “anticipates,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects,” and similar expressions. GLOSSARY OF TERMS AND ABBREVIATIONS We use the words “our,” “we” or “us” with respect to certain information that relates to Ameren, Ameren Missouri, and Ameren Illinois, collectively. When appropriate, subsidiaries of Ameren Corporation are named specifically as their various business activities are discussed. 2020 IRP – Integrated Resource Plan, a long-term nonbinding plan that Ameren Missouri filed with the MoPSC in September 2020, which includes Ameren Missouri’s preferred approach for meeting 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 2050. Ameren – Ameren Corporation and its subsidiaries on a consolidated basis. In references to financing activities, acquisition activities, or liquidity arrangements, Ameren is defined as Ameren Corporation, the parent. Ameren Companies – Ameren Corporation, Ameren Missouri, and Ameren Illinois, collectively, which are individual registrants within the Ameren consolidated group. Ameren Illinois – Ameren Illinois Company, an Ameren Corporation subsidiary that operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois, doing business as Ameren Illinois. Ameren Illinois Electric Distribution – An Ameren Corporation and Ameren Illinois financial reporting segment consisting of the rate- regulated electric distribution business of Ameren Illinois. Ameren Illinois Natural Gas – An Ameren Corporation and Ameren Illinois financial reporting segment consisting of the rate-regulated natural gas distribution business of Ameren Illinois. Ameren Illinois Transmission – An Ameren Illinois financial reporting segment consisting of the rate-regulated electric transmission business of Ameren Illinois. Ameren Missouri – Union Electric Company, an Ameren Corporation subsidiary that operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri, doing business as Ameren Missouri. Ameren Missouri is a financial reporting segment of Ameren Corporation. Ameren Services – Ameren Services Company, an Ameren Corporation subsidiary that provides support services, such as accounting, legal, treasury, and asset management services, to Ameren (parent) and its subsidiaries. Ameren Transmission – An Ameren Corporation financial reporting segment primarily consisting of the aggregated electric transmission businesses of Ameren Illinois and ATXI. ARO – Asset retirement obligations. ATM program – At-the-market equity distribution program. ATXI – Ameren Transmission Company of Illinois, an Ameren Corporation subsidiary that operates a FERC rate-regulated electric transmission business in the MISO. Baseload – The minimum amount of electric power delivered or required over a given period of time at a steady rate. Base rate – The service rate charged to customers, which varies by segmentation within customer classes, excludes rates applicable to riders, and is determined by the ratemaking process used to establish the annual revenue requirement applicable to such service. Btu – British thermal unit, a standard unit for measuring the quantity of heat energy required to raise the temperature of one pound of water by one degree Fahrenheit. CCR – Coal combustion residuals, which include fly ash, bottom ash, boiler slag, and flue gas desulfurization materials generated from burning coal to generate electricity. CCR Rule – Coal Combustion Residuals Rule, a rule promulgated by the EPA that established regulations for the disposal of CCR in landfills and surface impoundments, and the operation and closure of such landfills and surface impoundments. CO2 – Carbon dioxide. COVID-19 pandemic – The global pandemic resulting from the outbreak of the 2019 novel coronavirus, which causes coronavirus disease 2019 (COVID-19). Customer demand charges – Revenues from nonresidential customers based on their peak demand during a specified time interval. Cooling degree days – The summation of positive differences between the average daily temperature and a 65-degree Fahrenheit base. This statistic is useful as an indicator of electricity demand by residential and commercial customers for summer cooling. Credit Agreements – The Illinois Credit Agreement and the Missouri Credit Agreement, collectively. CSAPR – Cross-State Air Pollution Rule, an EPA rule that requires states that contribute to air pollution in downwind states to limit air emissions from fossil-fuel-fired electric generating units. CT – Combustion turbine, used primarily for peaking electric generation capacity. DCA – Delivery charge adjustment, a rate-adjustment mechanism that decouples natural gas revenues from actual sales volumes for Ameren Missouri’s natural gas business and allows Ameren Missouri to adjust customer rates without a traditional regulatory rate review, subject to MoPSC prudence reviews. This mechanism ensures that Ameren Missouri’s natural gas revenues are not affected by changes in sales volumes, including those resulting from deviations from normal weather conditions. This rate-adjustment mechanism will be replaced by the WNAR in late February 2022. Deferred payment arrangement – A payment option that allows certain Ameren Missouri and Ameren Illinois retail customers to pay a utility bill balance over a period of time, generally over a period of up to 12 months. On a temporary basis through June 2021, Ameren Illinois’ residential retail customers could have elected to pay a utility bill balance over a period of up to 18 months. Dekatherm – A standard unit of energy equivalent to approximately one million Btus. 1 DOE – Department of Energy, a United States government agency. DRPlus – Ameren Corporation’s dividend reinvestment and direct stock purchase plan. Electric margins – Electric revenues less fuel and purchased power costs. EMANI – European Mutual Association for Nuclear Insurance. EPA – Environmental Protection Agency, a United States government agency. ERISA – Employee Retirement Income Security Act of 1974, as amended. ESG – Environmental, social, and governance. Excess deferred income taxes – Amounts resulting from the revaluation of deferred income taxes subject to regulatory ratemaking, which will be collected from, or 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. Exchange Act – Securities Exchange Act of 1934, as amended. FAC – Fuel adjustment clause, a fuel and purchased power rate-adjustment mechanism that allows Ameren Missouri to recover or refund, through customer rates, 95% of the variance in net energy costs from the amount set in base rates without a traditional regulatory rate review, subject to MoPSC prudence reviews. FEJA – Future Energy Jobs Act, an Illinois law that allows Ameren Illinois to earn a return on its electric energy-efficiency investments, decouples electric distribution revenues from sales volumes, offers customer rebates for installing distributed generation, and includes extensions and modifications of certain IEIMA performance-based framework provisions, among other things. The decoupling provisions ensure that electric distribution revenues are not affected by changes in sales volumes, including those resulting from deviations from normal weather conditions. FERC – Federal Energy Regulatory Commission, a United States government agency that regulates utility businesses and associated activities of holding and related service companies, including Ameren (parent), Ameren Missouri, Ameren Illinois, ATXI, and Ameren Services. GAAP – Generally accepted accounting principles in the United States. Heating degree days – The summation of negative differences between the average daily temperature and a 65-degree Fahrenheit base. This statistic is useful as an indicator of demand for electricity and natural gas for winter heating by residential and commercial customers. ICC – Illinois Commerce Commission, a state agency that regulates Illinois utility businesses, including Ameren Illinois and ATXI. IEIMA – Illinois Energy Infrastructure Modernization Act, an Illinois law that established a performance-based formula process for determining electric distribution service rates. Ameren Illinois expects to establish electric distribution rates and reconcile related revenue requirements under this process through 2023. IETL – Illinois Energy Transition Legislation, Illinois legislation enacted in September 2021 that, among other things, gives Ameren Illinois the option to establish new electric distribution rates through either a traditional regulatory rate review, which may be based on a future test year, or an MYRP for a four-year period. Illinois Credit Agreement – Ameren’s and Ameren Illinois’ $1.1 billion senior unsecured credit agreement, which expires in December 2025, unless extended. IPA – Illinois Power Agency, a state government agency that has broad authority to assist in the procurement of electric power for residential and small commercial customers. IRS – Internal Revenue Service, a United States government agency. Kilowatthour – A measure of electricity consumption equivalent to the use of 1,000 watts of power over one hour. MATS – Mercury and Air Toxics Standards, an EPA rule that limits emissions of mercury and other air toxics from coal- and oil-fired electric generating units. MEEIA – A rate-adjustment mechanism allowed under the Missouri Energy Efficiency Investment Act, a Missouri law that allows electric utilities to recover costs and performance incentives, if any, related to MoPSC-approved customer energy-efficiency programs without a traditional regulatory rate review, subject to MoPSC prudence reviews. MEEIA 2019 – Ameren Missouri’s portfolio of customer energy-efficiency programs, recovery of lost electric margins, and performance incentives for March 2019 through December 2024, pursuant to Missouri law, as approved by the MoPSC in December 2018. Megawatthour or MWh – One thousand kilowatthours. MGP – Manufactured gas plant. MISO – Midcontinent Independent System Operator, Inc., an RTO. Missouri Credit Agreement – Ameren’s and Ameren Missouri’s $1.2 billion senior unsecured credit agreement, which expires in December 2025, unless extended. Missouri Environmental Authority – Environmental Improvement and Energy Resources Authority of the state of Missouri, a governmental body authorized to finance environmental projects by issuing tax-exempt bonds and notes. Mmbtu – One million Btus. Money pool – Borrowing agreements among Ameren and its subsidiaries to coordinate and provide for certain short-term cash and working capital requirements. Moody’s – Moody’s Investors Service, Inc., a credit rating agency. MoPSC – Missouri Public Service Commission, a state agency that regulates Missouri utility businesses, including Ameren Missouri. MTM – Mark-to-market. 2 MW – Megawatt. MYRP – Multi-year rate plan, a four-year electric distribution service rate plan allowed to be filed with the ICC under the IETL. Under a multi- year rate plan, the ICC would approve base rates for electric distribution service charged to customers for each calendar year of a four-year period. Ameren Illinois would be allowed to reconcile each year's base rates to its actual revenue requirement, subject to a reconciliation cap with exclusions for certain costs and riders, and adjustments to the ICC-determined ROE for performance incentives and penalties. Subject to a constructive outcome regarding the ICC’s determination of performance metrics, Ameren Illinois anticipates filing an MYRP for rates effective beginning in 2024. Native load – End-use retail customers whom Ameren Missouri or Ameren Illinois is obligated to serve by statute, franchise, contract, or other regulatory requirement. Natural gas margins – Natural gas revenues less natural gas purchased for resale. NAV – Net asset value per share. NEIL – Nuclear Electric Insurance Limited, which includes all of its affiliated companies. NERC – North American Electric Reliability Corporation. Net energy costs – Net energy costs, as defined in the FAC, which include fuel, fuel transportation, certain fuel additives, ash disposal costs and revenues, emission allowances, and purchased power costs, net of off-system sales and capacity revenues. Substantially all transmission revenues and charges are excluded from net energy costs. The MoPSC’s March 2020 electric rate order changed the FAC to include certain fuel additives and ash disposal costs and revenues as of April 2020. Pursuant to the MoPSC’s December 2021 electric rate order, effective February 28, 2022, all off-system sales from the High Prairie Renewable and Atchison Renewable energy centers will be excluded as those sales will be included in the RESRAM. Prior to this change, 95% of these sales were included in the FAC and 5% were included in the RESRAM. Net metering – Net metering allows customers who generate their own electricity or subscribe to receive output from eligible facilities to feed electricity they do not use back into the grid. The customers receive a credit for the energy they add to the grid. NOx – Nitrogen oxides. NPNS – Normal purchases and normal sales. NRC – Nuclear Regulatory Commission, a United States government agency that regulates commercial nuclear power plants and uses of nuclear materials. NSPS – New Source Performance Standards, provisions under the Clean Air Act. NSR – New Source Review provisions of the Clean Air Act, which include Nonattainment New Source Review and Prevention of Significant Deterioration regulations. NYSE – New York Stock Exchange, LLC. OCI – Other comprehensive income (loss) as defined by GAAP. Off-system sales revenues – Revenues from other than native load sales, including wholesale sales. PGA – Purchased gas adjustment tariffs, a rate-adjustment mechanism that permits prudently incurred natural gas costs to be recovered directly from utility customers without a traditional regulatory rate review, subject to regulatory prudence reviews. PHMSA – Pipeline and Hazardous Materials Safety Administration. 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. For Ameren Missouri, the PISA is effective through December 2023, unless Ameren Missouri requests and receives MoPSC approval of an extension through December 2028. QIP – Qualifying infrastructure plant, a rate-adjustment mechanism that provides Ameren Illinois’ natural gas business with recovery of, and a return on, qualifying infrastructure plant investments that are placed in service between regulatory rate reviews, subject to ICC prudence reviews. Without legislative action, the QIP will expire in December 2023. Rate base – The basis on which a rate-regulated utility is permitted to earn a WACC. This basis is the net investment in assets used to provide utility service, which generally consists of in-service property, plant, and equipment, net of accumulated depreciation and accumulated deferred income taxes, inventories, and, depending on jurisdiction, construction work in progress. Regulatory lag – The exposure to differences in costs incurred and actual sales volumes as compared with the associated amounts included in customer rates. Rate increase requests in traditional regulatory rate reviews can take up to 11 months to be acted upon by the MoPSC and the ICC. As a result, revenue increases authorized by regulators will lag changing costs and sales volumes when based on historical periods. RESRAM – Renewable energy standard rate-adjustment mechanism, a regulatory mechanism allowed under Missouri law that enables Ameren Missouri to recover costs relating to compliance with Missouri’s renewable energy standard, including recovery of investments in wind generation and other renewables, and earn a return at the applicable WACC on those investments not already provided for in customer rates or any other recovery mechanism by adjusting customer rates on an annual basis without a traditional regulatory rate review, subject to MoPSC prudence reviews. RESRAM regulatory assets will earn carrying costs at short-term interest rates. 3 Revenue requirement – The cost of providing utility service to customers, which is calculated as the sum of a utility’s recoverable operating expenses, a return at the weighted-average cost of capital on rate base, and an amount for income taxes, based on the currently applicable statutory income tax rates and amortization associated with excess deferred income taxes. RFP – Request for proposal. Rider – A rate-adjustment mechanism that allows for the recovery, or refund, through customer rates of amounts specified by the mechanism without a traditional regulatory rate review. ROE – Return on common equity. RTO – Regional transmission organization. S&P – S&P Global Ratings, a credit rating agency. SEC – Securities and Exchange Commission, a United States government agency. SERC – SERC Reliability Corporation, one of the regional electric reliability councils organized for coordinating the planning and operation of the nation’s bulk power supply. Smart Energy Plan – Ameren Missouri’s plan to upgrade Missouri’s electric grid through at least 2026, which assumes continuation of the PISA. Upgrades include investments to improve reliability and accommodate more renewable energy. SO2 – Sulfur dioxide. STEM – Science, technology, engineering, and math. TCJA – The Tax Cuts and Jobs Act of 2017, federal income tax legislation enacted in December 2017, which significantly changed the tax laws applicable to business entities. The TCJA includes specific provisions related to regulated public utilities. Test year – The selected period of time, typically a 12-month period, for which a utility’s historical or forecasted operating results are used to determine the revenue requirement in a regulatory rate review. Tracker – a regulatory recovery mechanism that allows for the deferral of differences between actual costs incurred and base level expenses included in customer rates as a regulatory asset or liability. The difference is included in base rates and recovered from, or refunded to, customers over a period of time as determined in a subsequent regulatory rate review. TSR – Total shareholder return, the cumulative return of a common stock or index over a specified period of time assuming all dividends are reinvested. VBA – Volume balancing adjustment, a rate-adjustment mechanism for Ameren Illinois’ natural gas business that decouples natural gas revenues from actual sales volumes and allows Ameren Illinois to adjust customer rates without a traditional regulatory rate review, subject to ICC prudence reviews. The rider ensures that Ameren Illinois’ natural gas revenues are not affected by changes in sales volumes, including those resulting from deviations from normal weather conditions, for residential and small nonresidential customers. WACC – Weighted-average cost of capital, which is the weighted-average cost of debt and equity, as allowed by the applicable regulator. WNAR – Weather normalization adjustment rider, a rate-adjustment mechanism that allows Ameren Missouri to adjust natural gas delivery service rates charged to residential customers without a traditional regulatory rate review, subject to MoPSC prudence reviews, when deviations from normal weather conditions cause natural gas revenues to vary from the related revenue requirement approved by the MoPSC in the previous regulatory rate review. This rate-adjustment mechanism will replace the DCA beginning February 28, 2022. Zero emission credit – A credit that represents the environmental attributes of one MWh of energy produced from certain zero emissions nuclear-powered generation facilities, which certain Illinois utilities are required to purchase pursuant to the FEJA. FORWARD-LOOKING STATEMENTS Statements in this report not based on historical facts are considered “forward-looking” and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such forward-looking statements have been made in good faith and are based on reasonable assumptions, there is no assurance that the expected results will be achieved. These statements include (without limitation) statements as to future expectations, beliefs, plans, projections, strategies, targets, estimates, objectives, events, conditions, and financial performance. In connection with the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause actual results to differ materially from those anticipated. The following factors, in addition to those discussed within Risk Factors under Part I, Item 1A, of 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 2019 remedy order for the Rush Island Energy Center, the July 2020 appeal filed by Ameren Missouri, Ameren Illinois, and ATXI challenging the refund period related to the FERC’s May 2020 order determining the allowed base ROE under the MISO tariff, and the July 2020 appeal filed by Ameren Missouri, Ameren Illinois, and ATXI challenging the FERC’s rehearing denials in the transmission formula rate revision cases; the length and severity of the COVID-19 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 and their use of deferred payment arrangements; the health, welfare, and availability of our 4 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 increased data security risks as a result of remote working arrangements for a significant portion of our workforce; and our ability to access the capital markets on reasonable terms and when needed; the effect of Ameren 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 of Ameren Illinois’ election to either utilize traditional regulatory rate reviews or MYRPs for electric distribution service ratemaking effective for rates beginning in 2024; the effect on Ameren Missouri’s investment plan and earnings if an extension to use PISA is not sought by Ameren Missouri or approved by the MoPSC; the effect on Ameren Missouri of any customer rate caps pursuant to Ameren Missouri’s election to use the PISA, including an extension of use beyond 2023, if requested by Ameren Missouri and approved by the MoPSC; the effects of changes in federal, state, or local laws and other governmental actions, including monetary, fiscal, 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; the effectiveness of Ameren Missouri’s customer energy-efficiency programs and the related revenues and performance incentives earned under its MEEIA programs; Ameren Illinois’ ability to achieve the performance standards applicable to its electric distribution business and electric customer energy- efficiency goals and the resulting impact on its allowed ROE; 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 of fuel, including nuclear fuel assemblies from the one NRC-licensed supplier of Ameren Missouri’s Callaway Energy Center assemblies; the cost and availability of transmission capacity for the energy generated by Ameren Missouri’s energy centers or required to satisfy Ameren Missouri’s energy sales; the effectiveness of our risk management strategies and our use of financial and derivative instruments; the ability to obtain sufficient insurance, or in the absence of insurance, the ability to timely recover uninsured losses from our customers; the impact of cyberattacks 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; 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 of the 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 that are affected by disruptions in the global supply chain caused by the COVID-19 pandemic; the impact of weather conditions and other natural phenomena on us and our customers, including the impact of system outages and the level of wind and solar resources; the construction, installation, performance, and cost recovery of generation, transmission, and distribution assets; the effects of failures of electric generation, electric and natural gas transmission or distribution, or natural gas storage facilities systems and equipment, which could result in unanticipated liabilities or unplanned outages; the operation of Ameren Missouri’s Callaway Energy Center, including planned and unplanned outages, as well as the ability to recover costs associated with such outages and the impact of such outages on off-system sales and purchased power, among other things; • • • • • • • • • • • • • • • • • • • • • • • • 5 • • • • • • • • • • • • Ameren Missouri’s ability to recover the remaining investment and decommissioning costs associated with the retirement of an energy center, as well as the ability to earn a return on that remaining investment and those decommissioning costs; the impact of current environmental laws and new, more stringent, or changing requirements, including those related to NSR, and CO2, other emissions and discharges, Illinois emission standards, cooling water intake structures, CCR, energy efficiency, and wildlife protection, that could limit or terminate the operation of certain of Ameren Missouri’s energy centers, increase our operating costs or investment requirements, result in an impairment of our assets, cause us to sell our assets, reduce our customers’ demand for electricity or natural gas, or otherwise have a negative financial effect; the impact of complying with renewable energy standards in Missouri and Illinois and with the zero emission standard in Illinois; Ameren Missouri’s ability to construct and/or acquire wind, solar, and other renewable energy generation facilities, retire energy centers, and implement new or existing customer energy efficiency programs, including any such construction, acquisition, retirement, or implementation in connection with its Smart Energy Plan, integrated resource plan, or emissions reduction goals, and to recover its cost of investment, 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 Missouri’s ability to use such credits; the cost of wind, solar, and other renewable generation and storage technologies; and our ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost for each facility; advancements in carbon-free generation and storage technologies, and the impact of constructive federal and state energy and economic policies with respect to those technologies; labor disputes, work force reductions, changes in future wage and employee benefits costs, including those resulting from changes in discount rates, mortality tables, returns on benefit plan assets, and other assumptions; the impact of negative opinions of us or our utility services that our customers, investors, legislators, regulators or other stakeholders may have or develop, which could result from a variety of factors, including failures in system reliability, failure to implement our investment plans or to protect sensitive customer information, increases in rates, negative media coverage, or concerns about ESG practices; the impact of adopting new accounting guidance; the effects of strategic initiatives, including mergers, acquisitions, and divestitures; legal and administrative proceedings; 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. ITEM 1. BUSINESS GENERAL PART I Ameren, formed in 1997 and headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Below is a summary description of Ameren’s principal subsidiaries – Ameren Missouri, Ameren Illinois, and ATXI. Ameren also has other subsidiaries that conduct other activities, such as providing shared services. A more detailed description can be found in Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. • • • Ameren Missouri operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri. Ameren Illinois operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois. ATXI operates a FERC rate-regulated electric transmission business in the MISO. For additional information about the development of our businesses, our business operations, and factors affecting our results of operations, financial position, and liquidity, see Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, and Note 1 – Summary of Significant Accounting Policies and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. 6 BUSINESS SEGMENTS Ameren has four segments: Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Transmission. The Ameren Missouri segment includes all of the operations of Ameren Missouri. Ameren Illinois Electric Distribution consists of the electric distribution business of Ameren Illinois. Ameren Illinois Natural Gas consists of the natural gas business of Ameren Illinois. Ameren Transmission primarily consists of the aggregated electric transmission businesses of Ameren Illinois and ATXI. Ameren Missouri has one segment. Ameren Illinois has three segments: Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Illinois Transmission. An illustration of the Ameren Companies’ reporting structures is provided below: (a) The Ameren Transmission segment also includes allocated Ameren (parent) interest charges, as well as other subsidiaries engaged in electric transmission project development and investment. RATES AND REGULATION Rates The rates that Ameren Missouri, Ameren Illinois, and ATXI are allowed to charge for their utility services significantly influence the results of operations, financial position, and liquidity of these companies and Ameren. The electric and natural gas utility industry is highly regulated. The utility rates charged to customers are determined by governmental entities, including the MoPSC, the ICC, and the FERC. Decisions by these entities are influenced by many factors, including the cost of providing service, the prudency of expenditures, the quality of service, regulatory staff knowledge and experience, customer intervention, and economic conditions, as well as social and political views. Decisions made by these governmental entities regarding customer rates are largely outside of our control. These decisions, as well as the regulatory lag involved in the process of obtaining approval for new customer rates, could have a material adverse effect on the results of operations, financial position, and liquidity of the Ameren Companies. The extent of the regulatory lag varies for each of Ameren’s electric and natural gas jurisdictions, with the Ameren Transmission and Ameren Illinois Electric Distribution businesses experiencing the least amount of regulatory lag. Depending on the jurisdiction, the effects of regulatory lag are mitigated by various means, including annual revenue requirement reconciliations, the decoupling of revenues from sales volumes to ensure revenues approved in a regulatory rate review are not affected by changes in sales volumes, the recovery of certain capital investments between traditional regulatory rate reviews, the level and timing of expenditures, the use of a future test year, and the use of trackers and riders. 7 The MoPSC regulates rates and other matters for Ameren Missouri. The ICC regulates rates and other matters for Ameren Illinois. The MoPSC and the ICC regulate non-rate utility matters for ATXI. ATXI does not have retail distribution customers; therefore, the MoPSC and the ICC do not have authority to regulate ATXI’s rates. The FERC regulates Ameren Missouri’s, Ameren Illinois’, and ATXI’s cost-based rates for the wholesale transmission and distribution of energy in interstate commerce and various other matters discussed below under General Regulatory Matters. For additional information on Ameren Missouri, Ameren Illinois, and ATXI rate matters, see Results of Operations and Outlook in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, Quantitative and Qualitative Disclosures About Market Risk under Part II, Item 7A, and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. The following table summarizes the key terms of the rate orders in effect for customer billings for each of Ameren’s rate-regulated utilities as of January 2022, except as noted: Ameren Missouri Electric service(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas delivery service(b) . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Electric distribution delivery service(f) . . . . . . . . . . . . . . . . Natural gas delivery service(g) . . . . . . . . . . . . . . . . . . . . . Electric transmission service(h) . . . . . . . . . . . . . . . . . . . . ATXI Electric transmission service(h) . . . . . . . . . . . . . . . . . . . . Rate Regulator Effective Rate Order Issued In MoPSC MoPSC December 2021(d) December 2021(e) ICC ICC FERC FERC December 2021 January 2021 (g) (g) Allowed ROE Percent of Common Equity Rate Base (in billions) Portion of Ameren’s 2021 Operating (a) Revenues (d) (e) 7.36% 9.67% 10.52% (d) (e) 51.00% 52.00% 54.02% 10.52% 59.96% $10.2 $0.3 $3.7 $2.1 $3.0 $1.4 50% 2% 25% 15% 5% 3% (a) (b) (c) (d) (e) (f) (g) (h) Includes pass-through costs recovered from customers, such as purchased power for electric distribution delivery service and natural gas purchased for resale for natural gas delivery service, and intercompany eliminations. New rates approved by the MoPSC’s December 2021 electric and natural gas rate orders will become effective on February 28, 2022. Ameren Missouri’s electric generation, transmission, and delivery service rates are bundled together and charged to retail customers under a combined electric service rate. Because the bundled rates charged to MoPSC retail customers include the revenue requirement associated with Ameren Missouri's FERC-regulated transmission services, the table above does not separately reflect a FERC-authorized rate base or allowed ROE. This rate order did not specify an ROE, but specified that Ameren Missouri’s September 30, 2021 capital structure, which was composed of 51.97% common equity, will be used in the PISA and RESRAM. This rate order did not specify an ROE or a capital structure. Ameren Illinois electric distribution delivery service rates are updated annually and become effective each January. This rate order was based on 2020 actual costs, expected net plant additions for 2021, and the annual average of the monthly yields during 2020 of the 30-year United States Treasury bonds plus 580 basis points, which was 1.56%. Ameren Illinois’ 2022 electric distribution delivery service revenues will be based on its 2022 actual recoverable costs, rate base, common equity percentage, and an allowed ROE, as calculated under the IEIMA’s performance-based formula ratemaking framework. This rate order was based on a 2021 future test year. Transmission rates are updated annually and become effective each January. They are determined by a company-specific, forward-looking formula ratemaking framework based on each year’s forecasted information. The 10.52% return, which includes a 50 basis points incentive adder for participation in an RTO, is based on the FERC’s May 2020 order. For additional information regarding this order and related requests for rehearing, see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. General Regulatory Matters Ameren Missouri, Ameren Illinois, and ATXI must receive FERC approval to enter into various transactions, such as issuing short-term debt securities and conducting certain acquisitions, mergers, and consolidations involving electric utility holding companies. In addition, Ameren Missouri, Ameren Illinois, and ATXI must receive authorization from the applicable state public utility regulatory agency to issue stock and long-term debt securities and to conduct mergers, affiliate transactions, and various other activities. Ameren Missouri, Ameren Illinois, and ATXI are also subject to mandatory reliability standards, including cybersecurity standards adopted by the FERC, to ensure the reliability of the bulk electric power system. These standards are developed and enforced by the NERC, pursuant to authority delegated to it by the FERC. Ameren Missouri, Ameren Illinois, and ATXI are members of the SERC. The SERC is one of six regional entities representing all or portions of 16 central and southeastern states under authority from the NERC for the purpose of implementing and enforcing reliability standards approved by the FERC. The regional entities of the NERC work to safeguard the reliability of the bulk power systems throughout North America. If any of Ameren Missouri, Ameren Illinois, or ATXI is found not to be in compliance with these mandatory reliability standards, it could incur substantial monetary penalties and other sanctions. 8 Under the Public Utility Holding Company Act of 2005, the FERC and the state public utility regulatory agencies in each state Ameren and its subsidiaries operate in may access books and records of Ameren and its subsidiaries that are found to be relevant to costs incurred by Ameren’s rate-regulated subsidiaries that may affect jurisdictional rates. The act also permits the MoPSC and the ICC to request that the FERC review cost allocations by Ameren Services to other Ameren subsidiaries. Operation of Ameren Missouri’s Callaway Energy Center is subject to regulation by the NRC. The license for the Callaway Energy Center expires in 2044. Ameren Missouri’s hydroelectric Osage Energy Center and pumped-storage hydroelectric Taum Sauk Energy Center, as licensed projects under the Federal Power Act, are subject to FERC regulations affecting, among other aspects, the general operation and maintenance of the projects. The licenses for the Osage Energy Center and the Taum Sauk Energy Center expire in 2047 and 2044, respectively. Ameren Missouri’s Keokuk Energy Center and its dam on the Mississippi River between Hamilton, Illinois, and Keokuk, Iowa, are operated under authority granted by an Act of Congress in 1905. For additional information on regulatory matters, see Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, and Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. Environmental Matters Our electric generation, transmission, and distribution and natural gas distribution and storage operations must comply with a variety of statutes and regulations relating to the protection of the environment and human health and safety. These environmental statutes and regulations are comprehensive and include the storage, handling, and disposal of waste materials, emergency planning and response requirements, limitations and standards applicable to discharges from our facilities into the air or water that are enforced through permitting requirements, and wildlife protection laws, including those related to endangered species. These environmental regulations could also affect the availability of, the cost of, and the demand for electricity and natural gas sold to Ameren Missouri’s and Ameren Illinois’ customers as well as the demand for off-system sales. Federal, state, and local authorities continually revise these regulations, which adds uncertainty to our planning process and to the ultimate implementation of these or other new or revised regulations. Failure to comply with these laws could have a material adverse effect on us. We could be subject to criminal or civil penalties by regulatory agencies, or we could be ordered by the courts to pay private parties. Except as indicated in this report, we believe that we are in material compliance with existing laws that currently apply to our operations. For discussion of environmental matters, including NOx and SO2 emission reduction requirements, regulation of CO2 emissions, wastewater discharge standards, remediation efforts, CCR management regulations, and a discussion of litigation against Ameren Missouri with respect to NSR, the Clean Air Act, and Missouri law in connection with projects at Ameren Missouri’s Rush Island Energy Center, see Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. TRANSMISSION Ameren owns an integrated transmission system that is composed of the transmission assets of Ameren Missouri, Ameren Illinois, and ATXI. Ameren also operates two MISO balancing authority areas: AMMO and AMIL. The AMMO balancing authority area includes the load and energy centers of Ameren Missouri, and had a peak demand of 7,390 MWs in 2021. The AMIL balancing authority area includes the load of Ameren Illinois, and had a peak demand of 8,504 MWs in 2021. The Ameren transmission system directly connects with 15 other balancing authority areas for the exchange of electric energy. Ameren Missouri, Ameren Illinois, and ATXI are transmission-owning members of the MISO. Ameren Missouri is authorized by the MoPSC to participate in the MISO through May 2024. Ameren Missouri is periodically required to make a filing with the MoPSC regarding its continued participation in the MISO. The next filing is due in 2023. SUPPLY OF ELECTRIC POWER Ameren Missouri Ameren Missouri’s electric supply is primarily generated from its energy centers. Factors that could cause Ameren Missouri to purchase power include, among other things, energy center outages, the fulfillment of renewable energy requirements, extreme weather conditions, the availability of power at a cost lower than its generation cost, and the lack of sufficient owned generation. Ameren Missouri files a long-term nonbinding integrated resource plan with the MoPSC every three years. The most recent integrated resource plan, filed in September 2020, includes Ameren Missouri’s preferred approach for meeting customers’ projected long-term energy needs in a cost-effective manner while maintaining system reliability and customer affordability. In August 2021, the MoPSC issued an order affirming the plan’s compliance with Missouri law. The plan targets cleaner and more diverse sources of energy generation, including solar, wind, hydro, and nuclear power, and supports increased investment in new energy technologies. It also includes expanding renewable sources by adding 3,100 MWs of renewable generation by the end of 2030 and a total of 5,400 MWs of renewable generation by 2040, 9 inclusive of the High Prairie Renewable and Atchison Renewable energy centers, the expectation that Ameren Missouri will seek NRC approval for an extension of the operating license for the Callaway Energy Center, expanding customer energy-efficiency programs, adding cost-effective demand response programs, accelerating the retirement dates of the Sioux and Rush Island coal-fired energy centers to 2028 and 2039, respectively, and retiring the remaining coal-fired energy centers as they reach the end of their useful lives, including the Meramec Energy Center by the end of 2022. The addition of a renewable generation facility is subject to obtaining necessary project approvals, including FERC approval and the issuance of a certificate of convenience and necessity by the MoPSC, as applicable. Ameren Missouri would be adversely affected if the MoPSC does not allow recovery of 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. In December 2021, the MoPSC issued an order in Ameren Missouri’s 2021 electric service regulatory rate review, which, among other things, approved a change in the depreciable lives of the Sioux and Rush Island energy centers’ assets consistent with Ameren Missouri’s 2020 IRP. Due to the NSR and Clean Air Act Litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of this report, Ameren Missouri plans to retire the Rush Island Energy Center prior to the 2039 date discussed above. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect an accelerated retirement date for the Rush Island Energy Center and the impact of new emission standards pursuant to the IETL, as discussed in Note 14 – Commitments and Contingencies, among other things. The next integrated resource plan is expected to be filed in September 2023. Ameren Missouri continues to evaluate its longer-term needs for new generating capacity. The need for investment in new sources of energy is dependent on several key factors, including continuation of and customer participation in energy-efficiency programs, the amount of distributed generation from customers, load growth, technological advancements, costs of generation alternatives, environmental regulation of coal-fired power plants, and state renewable energy requirements, which could lead to the retirement of current baseload assets before the end of their current useful lives or alterations in the way those assets operate, which could result in increased capital expenditures and/or increased operations and maintenance expenses. Because of the significant time required to plan, acquire permits for, and build a baseload energy center, Ameren Missouri continues to study alternatives and to take steps to preserve options to meet future demand. Steps include evaluating the potential for further diversification of Ameren Missouri’s generation portfolio through renewable energy generation, including wind and solar generation, extending the operating license for the Callaway Energy Center, additional customer energy-efficiency and demand response programs, distributed energy resources, and energy storage. Missouri law requires Ameren Missouri to offer solar rebates and net metering to certain customers that install renewable generation at their premises. The cost of the rebates are deferred as a regulatory asset under the RESRAM, and earn carrying costs at short-term interest rates. Customers that elect to enroll in net metering are allowed to net their generation against their usage within each billing month. Ameren Illinois In Illinois, while electric transmission and distribution service rates are regulated, power supply prices are not. Although electric customers are allowed to purchase power from an alternative retail electric supplier, Ameren Illinois is required to be the provider of last resort for its electric distribution customers. In 2021, 2020, and 2019, Ameren Illinois procured power on behalf of its customers for 23%, 23%, and 22%, respectively, of its total kilowatthour sales. Power purchased by Ameren Illinois for its electric distribution customers who do not elect to purchase their power from an alternative retail electric supplier comes either through procurement processes conducted by the IPA or through markets operated by the MISO. The IPA administers an RFP process through which Ameren Illinois procures its expected supply. The power and related procurement costs incurred by Ameren Illinois are passed directly to its electric distribution customers through a cost recovery mechanism. Transmission costs are charged to customers who purchase electricity from Ameren Illinois and to alternative retail electric suppliers through a cost recovery mechanism. The power, power procurement, and transmission costs are reflected in Ameren Illinois Electric Distribution’s results of operations, but do not affect Ameren Illinois Electric Distribution’s earnings because these costs are offset by corresponding revenues. Ameren Illinois charges distribution service rates to electric distribution customers who purchase electricity, regardless of supplier, which does affect Ameren Illinois Electric Distribution’s earnings. Illinois law requires Ameren Illinois to offer rebates and net metering to certain customers that install renewable generation or paired energy storage systems at their premises. The cost of the rebates are deferred as a regulatory asset, which earn a return at the applicable WACC. Customers that elect to receive a rebate and are enrolled in net metering are allowed to net their supply service charges, but not their distribution service charges. By law, Ameren Illinois’ electric distribution revenues are decoupled from sales volumes, which ensures that the electric distribution revenues authorized in a regulatory rate review are not affected by changes in sales volumes. POWER GENERATION Ameren Missouri owns energy centers that rely on a diverse fuel portfolio, including coal, nuclear, and natural gas, as well as renewable sources of generation, which include hydroelectric, wind, methane gas, and solar. All of Ameren Missouri’s coal-fired energy centers were constructed prior to 1978. The Callaway nuclear energy center began operation in 1984 and is licensed to operate until 2044. As of December 31, 2021, Ameren Missouri’s coal-fired energy centers represented 10% and 20% of Ameren’s and Ameren Missouri’s rate base, respectively. See Item 2 – Properties under Part I of this report for information regarding Ameren Missouri’s energy centers. 10 Coal Ameren Missouri has an ongoing need for coal as fuel for generation, and pursues a price-hedging strategy consistent with this requirement. Ameren Missouri has agreements in place to purchase and transport coal to its energy centers. While Ameren Missouri has minimum purchase obligations associated with these agreements, the majority of these agreements are not associated with any specific coal- fired energy center. As of December 31, 2021, Ameren Missouri had price-hedged 99% of its expected coal supply and 100% of its coal transportation requirements for generation in 2022. Ameren Missouri has additional coal supply under contract through 2025. The Powder River Basin coal transport agreements that Ameren Missouri has with Union Pacific Railroad and Burlington Northern Santa Fe Railway are currently set to expire at the end of 2024. Ameren Missouri burned approximately 16.5 million tons of coal in 2021. About 98% of Ameren Missouri’s coal is purchased from the Powder River Basin in Wyoming, which has a limited number of suppliers. The remaining coal is typically purchased from the Illinois Basin. Targeted coal inventory levels may be adjusted because of generation levels or uncertainties of supply due to potential work stoppages, delays in coal deliveries, equipment breakdowns, and other factors. Deliveries from the Powder River Basin have occasionally been restricted because of rail congestion, staffing and equipment issues, infrastructure maintenance, derailments, weather, and supplier financial hardship. Coal suppliers in the Powder River Basin are experiencing financial hardship because of a decrease in demand resulting from increased natural gas and renewable energy generation, and the impact of environmental regulations and concerns related to coal-fired generation. These financial hardships have resulted in bankruptcy filings by certain coal suppliers in recent years. As of December 31, 2021, coal inventories at the Sioux and Rush Island energy centers were near targeted levels, and coal inventories at the Labadie Energy Center were below targeted levels due to transportation disruptions in 2021. Ameren Missouri is actively managing inventories at the Meramec Energy Center in preparation for its expected 2022 retirement. Disruptions in coal deliveries could cause Ameren Missouri to pursue a strategy that could include reducing off-system sales of power during low-margin periods, buying higher-cost fuels to generate required electricity, and purchasing power from other sources. Nuclear The production of nuclear fuel involves the mining and milling of uranium ore to produce uranium concentrates, the conversion of uranium concentrates to uranium hexafluoride gas, the enrichment of that gas, the conversion of the enriched uranium hexafluoride gas into uranium dioxide fuel pellets, and the fabrication into fuel assemblies. Ameren Missouri has entered into uranium, uranium conversion, uranium enrichment, and fabrication contracts to procure the fuel supply for its Callaway Energy Center. The Callaway Energy Center has historically required refueling at 18-month intervals. During its return to full power after the completion of the last refueling and maintenance outage in late December 2020, the Callaway Energy Center experienced a non-nuclear operating issue related to its generator. After replacement of certain key components of the generator, the energy center returned to service in early August 2021. The next refueling is scheduled for the spring of 2022. Ameren Missouri has inventories and supply contracts sufficient to meet all of its uranium (concentrate and hexafluoride), conversion, and enrichment requirements at least through the 2026 refueling. Fuel fabrication service contracts extend through 2023, and procurement efforts are ongoing to extend this coverage. RENEWABLE ENERGY AND ZERO EMISSION STANDARDS Missouri and Illinois laws require electric utilities to include renewable energy resources in their portfolios. Ameren Missouri and Ameren Illinois satisfied their renewable energy portfolio requirements in 2021. Ameren Missouri In Missouri, utilities were required to purchase or generate electricity equal to at least 15% of native load sales from renewable energy sources in 2021. The requirement, which is applicable to 2022 and each year thereafter, is subject to an average 1% annual increase on customer rates over any 10-year period. At least 2% of the annual renewable energy requirement must be derived from solar energy. Ameren Missouri expects to satisfy the nonsolar requirement in 2022 with its High Prairie Renewable, Atchison Renewable, Keokuk, and Maryland Heights energy centers, a 102-MW power purchase agreement with a wind farm operator, and immaterial renewable energy credit purchases in the market. The High Prairie Renewable and Atchison Renewable energy centers are wind generation facilities. The Keokuk Energy Center generates electricity using a hydroelectric dam located on the Mississippi River. The Maryland Heights Energy Center generates electricity by burning methane gas collected from a landfill. Ameren Missouri is meeting the solar energy requirement by purchasing solar- generated renewable energy credits from customer-installed systems and by generating energy at its solar facilities. Ameren Illinois In accordance with Illinois law, Ameren Illinois is required to collect funds from all electric distribution customers to fund IPA procurement events for renewable energy credits. The IPA establishes its long-term renewable resources procurement plans in a filing made every two years. Based on IPA procurement events, Ameren Illinois has contractual commitments of approximately 0.9 million wind renewable energy credits per year and approximately 1.1 million solar renewable energy credits per year. Ameren Illinois has also entered into 20-year 11 contracts, ending in 2032, to purchase approximately 0.6 million wind renewable energy credits per year. The IETL, which was enacted in September 2021, increased the amount Ameren Illinois collects from customers to fund IPA renewable energy credit procurement events from $1.81 per MWh to $4.58 per MWh, beginning in February 2022. Also, pursuant to the IETL, if funds collected from customers are not used to procure renewable energy credits, they would be refunded to customers pursuant to a reconciliation proceeding, the first of which is expected to be initiated after August 2023. Based on amounts collected from customers and renewable energy credit purchases under contract, Ameren Illinois does not expect the first reconciliation proceeding to result in refunds to customers. The IPA is expected to file its first long-term renewable resources procurement plan under the IETL in March 2022, which, once approved by the ICC, will establish the 2022 and 2023 renewable energy credit procurement targets. Illinois law also required Ameren Illinois to enter into contracts for zero emission credits in an amount equal to approximately 16% of the actual amount of electricity delivered to retail customers during calendar year 2014, pursuant to Illinois’ zero emission standard. As a result of a 2018 IPA procurement event, which was approved by the ICC, Ameren Illinois entered into agreements to acquire zero emission credits through 2026. Annual zero emission credit commitment amounts will be published by the IPA each May prior to the start of the subsequent planning year. Both renewable energy credits and zero emission credits have cost recovery mechanisms, which allow Ameren Illinois to collect from, or refund to, customers differences between actual costs incurred from the resulting contracts and the amounts collected from customers. CUSTOMER ENERGY-EFFICIENCY PROGRAMS Ameren Missouri and Ameren Illinois have implemented energy-efficiency programs to educate their customers and to help them become more efficient energy consumers. These programs provide incentives to customers for installing newer, more efficient technology, and for using energy in a more conservation-minded manner. As a component of the energy-efficiency programs, Ameren Missouri and Ameren Illinois have invested in electric smart meters to provide customers more visibility to their energy consumption and facilitate more efficient use of energy. As of December 31, 2021, smart meters have been installed for approximately 37% of Ameren Missouri’s electric customers and nearly all of Ameren Illinois’ electric customers. Ameren Missouri In Missouri, the Missouri Energy Efficiency Investment Act established a rider that, among other things, allows electric utilities to recover costs with respect to MoPSC-approved customer energy-efficiency programs. The law requires the MoPSC to ensure that a utility’s financial incentives are aligned to help customers use energy more efficiently, to provide timely cost recovery, and to provide earnings opportunities associated with cost-effective energy-efficiency programs. Missouri does not have a law mandating energy-efficiency programs. In 2018, the MoPSC issued an order approving Ameren Missouri’s MEEIA 2019 plan. The plan includes a portfolio of customer energy- efficiency 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 $70 million in 2022 and $75 million in 2023. 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 are achieved for 2021 and 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. Through 2021, Ameren Missouri has invested $202 million in MEEIA 2019 customer energy-efficiency programs. Additionally, as part of its Smart Energy Plan, Ameren Missouri has invested $195 million in smart meters since 2019. The MEEIA 2019 plan includes the continued use of the MEEIA rider. The MEEIA rider allows Ameren Missouri to collect from, or refund to, customers any difference between actual program costs, lost electric margins, and any performance incentive and the amounts collected from customers, without a traditional regulatory rate review, subject to MoPSC prudence reviews, until lower volumes resulting from the MEEIA programs are reflected in base rates. Customer rates, based upon both forecasted program costs and lost electric margins and collected via the MEEIA rider, are reconciled annually to actual results. Ameren Illinois State law requires Ameren Illinois to offer customer energy-efficiency programs, and imposes electric energy-efficiency savings goals and a maximum annual amount of investment in electric energy-efficiency programs. Every four years, Ameren Illinois is required to file a four-year electric energy-efficiency plan with the ICC. In July 2021, the ICC issued an order approving Ameren Illinois’ electric and natural gas energy-efficiency plans for 2022 through 2025, as well as regulatory recovery mechanisms. The order authorized electric and natural gas energy-efficiency program expenditures of $425 million and $66 million, respectively, over the four-year period. Subsequent to this order, the IETL was enacted, which increased the allowed annual investments in electric energy-efficiency programs from approximately $100 million to approximately $120 million for the 2022 to 2025 period, among other things. Ameren Illinois expects to file a revised energy-efficiency plan with the ICC by early March 2022 to reflect the increased level of annual investments allowed under the IETL. Pursuant to the IETL, the annual maximum amount of investment for 2026 to 2029 is approximately $120 million and may increase by up to approximately $30 million depending on the election of certain customers to participate in the programs. 12 Illinois law allows Ameren Illinois to earn a return on its electric energy-efficiency program investments. Ameren Illinois’ electric energy- efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC, with the ROE 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 approves Ameren Illinois’ four-year electric energy-efficiency plans, the ICC has the ability to reduce the amount of approved 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 included in the electric distribution service performance-based formula ratemaking framework. Ameren Illinois’ natural gas energy-efficiency program costs are recovered through a rider. NATURAL GAS SUPPLY FOR DISTRIBUTION Ameren Missouri and Ameren Illinois are responsible for the purchase and delivery of natural gas to their customers. Ameren Missouri and Ameren Illinois each develop and manage a portfolio of natural gas supply resources. These resources include firm natural gas supply agreements with producers, firm interstate and intrastate transportation capacity, firm no-notice storage capacity leased from interstate pipelines, and on-system storage facilities to maintain natural gas deliveries to customers throughout the year and especially during peak demand periods. Ameren Missouri and Ameren Illinois primarily use Panhandle Eastern Pipe Line Company, Trunkline Gas Company, Natural Gas Pipeline Company of America, Mississippi River Transmission Corporation, Northern Border Pipeline Company, and Texas Eastern Transmission Corporation interstate pipeline systems to transport natural gas to their systems. In addition to transactions requiring physical delivery, certain financial instruments, including those entered into in the New York Mercantile Exchange futures market and in the over-the-counter financial markets, are used to hedge the price paid for natural gas. Natural gas supply costs are passed on to customers of Ameren Missouri and Ameren Illinois under PGA clauses, subject to prudence reviews by the MoPSC and the ICC. As of December 31, 2021, Ameren Missouri and Ameren Illinois had price-hedged 96% and 93%, respectively, of their expected remaining natural gas supply requirements for the peak winter season through March 2022. For additional information on our fuel, purchased power, and natural gas for distribution supply, see Results of Operations and Liquidity and Capital Resources in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, and Commodity Price Risk under Part II, Item 7A, of this report. Also see Note 1 – Summary of Significant Accounting Policies, Note 7 – Derivative Financial Instruments, Note 13 – Related-party Transactions, Note 14 – Commitments and Contingencies, and Note 15 – Supplemental Information under Part II, Item 8 of this report. HUMAN CAPITAL MANAGEMENT The execution of Ameren’s core strategy to invest and operate in a manner consistent with existing regulatory frameworks, advocate for responsible policies, and capitalize on investment opportunities to deliver superior customer and shareholder value is driven by the capabilities and engagement of our workforce. Ameren’s workforce strategy is designed to promote a skilled and diverse workforce that is prepared to deliver on Ameren’s mission (To Power the Quality of Life) and vision (Leading the Way to a Sustainable Energy Future), both today and in the future. Our workforce strategy is anchored in four key pillars: Culture, Leadership, Talent, and Rewards, which are discussed further below. Foundational to our workforce strategy are our core values of: • Safety and security • Commitment to excellence • Respect • Accountability • Diversity, equity, and inclusion • Integrity • Teamwork • Stewardship Ameren’s chief executive officer and chief human resources officer, with the support of other leaders of the Ameren Companies, are responsible for developing and executing our workforce strategy. In addition to reviewing and determining the Ameren Companies’ compensation practices and policies for the chief executive officer and other executive officers, the Human Resources Committee of Ameren’s board of directors is responsible for oversight of Ameren’s human capital management practices and policies, including those related to diversity, equity, and inclusion. The Human Resources Committee and Ameren’s board of directors are updated regularly on human capital matters. Culture We strive to cultivate a values-based “All-In” culture that enables the sustainable execution of our core strategy and reflects the following characteristics: • We Care about our customers, our communities, and each other • We Serve with Passion • We Deliver for our customers and stakeholders, today and tomorrow • We Win Together as a result of our teamwork and collaboration 13 We design our human capital management practices and policies to reinforce our core values, foster our culture, and drive employee engagement. In doing so, we strive to align our employees to our mission and vision, improve safety, enhance innovation, increase productivity, attract and retain top talent, and recognize employee contributions, among other things. We assess employee engagement through a variety of channels. As a part of our assessment, we conduct confidential employee engagement surveys at least annually to identify areas of strength and opportunities for improvement in our employees’ experience, and take actions aimed at increasing employee engagement. As a part of our All-In culture, every employee is expected to challenge any unsafe act, complete each workday safely, and provide feedback on safety and security matters. In addition to comprehensive safety and security standards, and mandatory health, safety, and security training programs for applicable employees, we promote programs designed to encourage employees to provide feedback on practices or actions that could harm employees, customers, or the Ameren Companies, including perceived issues related to safety, security (both physical and cyber), ethics and compliance violations, or acts of discrimination. For additional information about the actions taken that were designed to protect the safety of our employees and customers during the COVID-19 pandemic, see The COVID-19 Pandemic section below. We seek to foster diversity, equity, and inclusion across our organization. We contribute to community-based organizations, hold diversity, equity, and inclusion leadership summits for employees and community leaders, and offer various training programs. We also offer a program to provide paid-time off for employees who engage in volunteer or learning opportunities with organizations that support diversity, equity, and inclusion. We also have employee resource groups, which bring together groups of employees who share common interests or backgrounds. Within these groups, employees collaborate to address concerns and provide training and development opportunities related to challenges or barriers, and offer support for each other, among other things. Leadership Ameren’s leaders play a critical role in setting and executing Ameren’s strategic initiatives, modeling our values and culture, and engaging and enabling the workforce. As such, we seek to develop a strong, diverse leadership team. Management engages in an extensive succession planning process annually, which includes the involvement by Ameren’s board of directors. We develop our leaders both individually, through job rotations, work experiences, and leadership development programs, and as a team, through collaborative learning and mentoring relationships. Throughout the year, we offer a variety of forums intended to connect our leaders to our mission, values, strategy and culture, build leadership skills and capabilities, and to promote connection and inclusion. In addition, we evaluate our organizational structure and make adjustments and expand roles to facilitate execution of our strategy and organizational efficiency. Talent In order to attract and retain a skilled and diverse workforce, we promote an inclusive work environment, provide opportunities for employees to expand their knowledge and skill sets, and support career development. Our talent management initiatives include a wide range of recruiting partnerships and programs, including those programs discussed below. Our onboarding efforts are designed to ensure early engagement, including the opportunity to participate in mentoring programs. Additionally, employees are encouraged to participate in technical, professional, and leadership development opportunities, and outreach initiatives to engage with the communities that we serve, among other things. As our business needs change, we remain focused on ensuring that our workforce has the tools and skills necessary to deliver on our strategic initiatives. We have established programs to recruit early and mid-career talent to further enhance the diversity of our workforce pipelines. These programs include skilled craft education and training for individuals interested in skilled craft roles, an intern/co-op program that serves as a pipeline for STEM-related careers, a career reentry program for experienced professionals transitioning from voluntary career breaks, a program for individuals transitioning from military service, and an early career rotation program. Additionally, each year management and the Human Resources Committee of Ameren’s board of directors review the diversity of our workforce, leadership team, and leadership development pipeline, as well as the actions taken to further enhance the diversity of our leadership team. Workforce The majority of our workforce is comprised of skilled-craft and STEM-related professional and technical employees. Our workforce has been stable, with a total attrition rate of 8% in 2021. The majority of employee attrition is attributable to employee retirements, generally 14 allowing for thoughtful workforce and succession planning in advance of these planned transitions. The following table presents our employee count and their average tenure as of December 31, 2021, and the attrition rate in 2021: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employee Count 9,116 3,998 3,239 1,879 Average Tenure (in years) 14 15 14 11 Attrition Rate 8% 7% 9% 9% Ameren’s workforce is diverse in many ways. At the officer level, which represents 54 individuals, 22% are female, and 20% are racially and/or ethnically diverse. The following table presents our total employee population that is represented by a collective bargaining unit, is a female, or is racially and/or ethnically diverse at December 31, 2021: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48% 58% 55% 12% The following table presents Ameren’s employees by generation at December 31, 2021: Collective Bargaining Unit Female 24% 17% 24% 40% Racially and/or Ethnically Diverse 16% 15% 13% 23% Generation Description Ameren Ameren Missouri Ameren Illinois Ameren Services Baby Boomer (birth years between 1946 and 1964) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Generation X (birth years between 1965 and 1980) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Millennials (birth years between 1981 and 1996) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Generation Z/Post Millennial (birth years after 1997) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20% 41% 36% 3% 21% 41% 35% 3% 19% 40% 39% 2% 20% 42% 35% 3% Collective bargaining units at Ameren’s subsidiaries consist of the International Brotherhood of Electrical Workers, the International Union of Operating Engineers, the Laborer’s International Union of North America, the United Association of Plumbers and Pipefitters, and the United Government Security Officers of America. The Ameren Companies expect continued constructive relationships with their respective labor unions. All of the Ameren Missouri collective bargaining unit contracts expire in 2022. The Ameren Illinois collective bargaining unit contracts expire in 2022 and 2023, which cover 92% and 8% of represented employees, respectively. Ameren Missouri and Ameren Illinois expect to renew these contracts prior to their expiration. Rewards The primary objective of our rewards program is to provide a total rewards package that attracts and retains a talented workforce and reinforces strong performance in a financially sustainable manner. Management continuously evaluates our core benefits in an effort to create a market-competitive, performance-based, shareholder-aligned total rewards package with a view towards balancing employee value and financial sustainability. We recognize that the rewards package required to attract and retain talent over the long term is about more than pay and benefits; it is about the total employee experience and supporting their overall well-being. In addition to base salary, medical benefits, and retirement benefits, including 401(k) savings and pension, our total rewards package includes short-term incentives and long- term stock-based compensation for certain employees. Further, we offer our employees various programs that encourage overall well-being, including wellness and employee assistance programs. We strive to provide a competitive and sustainable rewards package that supports our ability to attract, engage, and retain a talented and diverse workforce, while at the same time reinforcing and rewarding strong performance. THE COVID-19 PANDEMIC 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 2021, compared to 2020, and total sales volume levels were more comparable to pre-pandemic levels, there has been a shift in sales volumes by customer class, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect of the 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. Although restrictions on social activities and nonessential businesses implemented in our service territories in 2020 have been relaxed, additional restrictions may be imposed in the future. 15 During the COVID-19 pandemic, Ameren has taken significant actions designed to protect the safety of our employees and customers, including restricting travel for employees, implementing work-from-home policies, offering voluntary leave of absence arrangements and flexible reduced work schedules, enhancing paid time off programs for impacted employees, securing and supplying personal protective equipment, and implementing work practices to protect the safety of our employees and customers. In addition to our existing employee assistance program, we continue to provide additional resources on physical, emotional, and financial well-being throughout the pandemic. We are capitalizing on the opportunities presented by the COVID-19 pandemic, including advancing the digital enablement of our workforce and enhancing our facilities and workforce policies and practices to increase collaboration and productivity. For further discussion of the impact to our businesses related to the pandemic and regulatory mechanisms that reduce these impacts, see Overview, Results of Operations, and Outlook in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, and Note 1 – Summary of Significant Accounting Policies and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. INDUSTRY ISSUES We are facing issues common to the electric and natural gas utility industry. These issues include: • • • • • • • • • • • • • • • • • • • • • • • the potential for changes in laws, regulations, enforcement efforts, and policies at the state and federal levels; corporate tax law changes, as well as additional interpretations, regulations, amendments, or technical corrections that affect the amount and timing of income tax payments, reduce or limit the ability to claim certain deductions and use carryforward tax benefits and/or credits, or result in rate base reductions; cybersecurity risks, cyber attacks, including ransomware and other ransom-based attacks, hacking, social engineering, and other forms of malicious cybersecurity and/or privacy events, which could result in the loss of operational control of energy centers and electric and natural gas transmission and distribution systems and/or the theft or inappropriate release of certain types of information, including sensitive customer, employee, financial, and operating system information; political, regulatory, and customer resistance to higher rates; the potential for more intense competition in generation, supply, and distribution, including new technologies and their declining costs; the impact and effectiveness of vegetation management programs; the potential for reliability issues as fossil-fuel-fired and nuclear generation facilities are retired and replaced with renewable energy generation sources, and the impact on customer rates; the modernization of the electric grid to accommodate a two-way flow of electricity and increase capacity for distributed generation interconnection; net metering rules and other changes in existing regulatory frameworks and recovery mechanisms to address the allocation of costs to customers who own generation resources that enable them both to sell power to us and to purchase power from us through the use of our transmission and distribution assets; legislation or programs to encourage or mandate energy efficiency, energy conservation, and renewable sources of power, and the lack of consensus as to how those programs should be paid for; pressure and uncertainty on customer growth and sales volumes in light of the COVID-19 pandemic and other economic conditions, distributed generation, energy storage, technological advances, and energy-efficiency or conservation initiatives; changes in the structure of the industry as a result of changes in federal and state laws, including the formation and growth of independent transmission entities; changes in the allowed ROE on FERC-regulated electric transmission assets; the availability of fuel and fluctuations in fuel prices; the availability of materials and equipment, and the potential disruptions in supply chains, including those resulting from the COVID-19 pandemic; the availability of a skilled work force, including transferring the specialized knowledge of those who are nearing retirement to employees succeeding them; inflationary pressures on the prices of commodities, labor, services, materials, and supplies; the potential for reduced efficiency and productivity due to the transition to hybrid remote working arrangements for non-field employees; regulatory lag; the influence of macroeconomic factors on yields of United States Treasury securities and on the allowed ROE provided by regulators; higher levels of infrastructure and technology investments and adjustments to customer rates associated with the refund of excess deferred income taxes that have resulted in, and are expected to continue to result in, negative or decreased free cash flow, which is defined as cash flows from operating activities less cash flows from investing activities and dividends paid; the demand for access to renewable energy generation at rates acceptable to customers; public concerns about the siting of new facilities, and challenges that members of the public can assert against applications for governmental permits and other approvals required to site and build new facilities that can result in significant cost increases, delays and denial of the permits and approvals by the regulators; 16 • • • • • • • • complex new and proposed environmental laws including statutes, regulations, and requirements, such as air and water quality standards, mercury emissions standards, limitations on the use of natural gas in generation, CCR management requirements, and potential CO2 limitations, which may limit, or result in the cessation of, the operation of electric generating units; public concerns about the potential environmental impacts from the combustion of fossil fuels, as well as pressure from public interest groups regarding limiting the use of natural gas; certain investors’ concerns about investing in utility companies that have coal-fired generation assets; increasing scrutiny by investors and other stakeholders of ESG practices; aging infrastructure and the need to construct new power generation, transmission, and distribution facilities, which have long time frames for completion, with limited long-term ability to predict power and commodity prices and regulatory requirements; public concerns about nuclear generation, decommissioning, and the disposal of nuclear waste; industry reputational challenges resulting from inappropriate lobbying and similar activities by certain utility companies; and consolidation of electric and natural gas utility companies. We are monitoring all these issues. Except as otherwise noted in this report, we are unable to predict what impact, if any, these issues will have on our results of operations, financial position, or liquidity. For additional information, see Risk Factors under Part I, Item 1A, Outlook in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, and Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, and Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. 17 OPERATING STATISTICS The following tables present key electric and natural gas operating statistics for Ameren for the past three years: Electric Operating Statistics – Year Ended December 31, 2021 2020 2019 Electric Sales – kilowatthours (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Street lighting and public authority . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri retail load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Electric Distribution(a): Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Street lighting and public authority . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Electric Distribution total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Eliminate affiliate sales . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric Operating Revenues (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other, including street lighting and public authority . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13,366 13,556 4,151 81 31,154 7,425 38,579 11,620 11,795 11,076 430 34,921 (412) 73,088 1,445 1,126 280 170 Ameren Missouri retail load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3,021 Off-system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 191 Ameren Missouri total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3,212 Ameren Illinois Electric Distribution: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other, including street lighting and public authority . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 933 545 135 26 Ameren Illinois Electric Distribution total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,639 Ameren Transmission: Ameren Illinois Transmission(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ ATXI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Eliminate affiliate revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Transmission total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other and intersegment eliminations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 365 199 (2) 562 (116) Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,297 13,267 13,117 4,158 88 30,630 7,578 38,208 11,491 11,414 10,674 442 34,021 (322) 71,907 1,373 1,025 261 155 2,814 170 2,984 867 486 124 21 1,498 329 194 — 523 (94) 4,911 $ $ $ $ $ $ $ $ 13,532 14,269 4,242 99 32,142 5,477 37,619 11,675 12,341 11,587 491 36,094 (84) 73,629 1,403 1,157 278 127 2,965 144 3,109 848 497 127 32 1,504 288 176 — 464 (96) 4,981 $ $ $ $ $ $ $ $ (a) (b) Sales for which power was supplied by Ameren Illinois as well as alternative retail electric suppliers. In 2021, 2020, and 2019, Ameren Illinois procured power on behalf of its customers for 23%, 23%, and 22%, respectively, of its total kilowatthour sales. Includes $66 million, $52 million, and $62 million in 2021, 2020, and 2019, respectively, of electric operating revenues from transmission services provided to Ameren Illinois Electric Distribution. 18 Electric Operating Statistics – Year Ended December 31, Ameren Missouri fuel costs (cents per kilowatthour generated)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Source of Ameren Missouri energy supply: 2021 1.46 ¢ Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73.0 % 10.5 Hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wind . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Methane gas and solar . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power – wind . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power – other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.2 3.7 1.0 0.2 0.6 6.8 2020 1.38 ¢ 67.3 % 19.4 4.5 — 0.5 0.5 0.6 7.2 2019 1.38 ¢ 63.4 % 23.3 5.0 — 0.5 0.2 0.7 6.9 100.0 % 100.0 % 100.0 % (a) Ameren Missouri fuel costs exclude $1 million, $(49) million and $5 million in 2021, 2020, and 2019, respectively, for changes in FAC recoveries. Natural Gas Operating Statistics – Year Ended December 31, 2021 2020 2019 Natural Gas Sales – dekatherms (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural Gas Operating Revenues (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 4 1 9 21 54 16 4 100 174 195 79 34 4 24 Ameren Missouri total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 141 Ameren Illinois Natural Gas: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other and intercompany eliminations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 657 172 35 93 957 (1) Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,097 Rate Base Statistics – At December 31, 2021 Rate Base (in billions): Electric transmission and distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas transmission and distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.5 2.7 Coal generation: Labadie Energy Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sioux Energy Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rush Island Energy Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Meramec Energy Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Coal generation total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Renewable generation (hydroelectric, wind, solar, methane gas) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.9 0.7 0.4 0.1 2.1 1.5 1.5 0.3 7 3 1 9 20 55 15 7 96 173 193 76 29 4 16 125 541 136 14 69 760 (2) 883 2020 12.1 2.4 0.9 0.7 0.4 0.1 2.1 1.5 1.0 0.3 $ $ $ $ $ $ 7 4 1 9 21 61 19 4 101 185 206 81 34 4 15 134 570 154 13 60 797 (2) 929 2019 10.7 2.1 0.9 0.6 0.5 0.1 2.1 1.4 0.5 0.4 $ $ $ $ $ $ Rate base total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 21.6 $ 19.4 $ 17.2 19 AVAILABLE INFORMATION The Ameren Companies make available free of charge through Ameren’s website (www.amereninvestors.com) their annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports filed with or furnished to the SEC pursuant to Sections 13(a) or 15(d) of the Exchange Act as soon as reasonably possible after such reports are electronically filed with, or furnished to, the SEC. These documents are also available through the SEC’s website (www.sec.gov). Ameren’s website is a channel of distribution for material information about the Ameren Companies. Financial and other material information is routinely posted to, and accessible at, Ameren’s website. The Ameren Companies also make available free of charge through Ameren’s website the charters of Ameren’s board of directors’ Audit and Risk Committee, Human Resources Committee, Nominating and Corporate Governance Committee, Finance Committee, and Nuclear, Operations and Environmental Sustainability Committee; the corporate governance guidelines; a policy regarding communications to the board of directors; a policy and procedures document with respect to related-person transactions; a code of ethics applicable to all directors, officers and employees; a supplemental code of ethics for principal executive and senior financial officers; and a director nomination policy that applies to the Ameren Companies. The information on Ameren’s website, or any other website referenced in this report, is not incorporated by reference into this report. ITEM 1A. RISK FACTORS Investors should review carefully the following material risk factors and the other information contained in this report. The risks that the Ameren Companies face are not limited to those in this section. There may be further risks and uncertainties that are not presently known or that are not currently believed to be material that may adversely affect the results of operations, financial position, and liquidity of the Ameren Companies. REGULATORY AND LEGISLATIVE RISKS We are subject to extensive regulation of our businesses. We are subject to federal, state, and local regulation. The extensive regulatory frameworks, some of which are more specifically identified in the following risk factors, regulate, among other matters, the electric and natural gas utility industries; the rate and cost structure of utilities, including an allowed ROE; the operation of nuclear power plants; the construction and operation of generation, transmission, and distribution facilities; the acquisition, disposal, depreciation and amortization of assets and facilities; the electric transmission system reliability; and wholesale and retail competition. In the planning and management of our operations, we must address the effects of existing and proposed laws and regulations and potential changes in our regulatory frameworks, including initiatives by federal and state legislatures, RTOs, utility regulators, and taxing authorities. Significant changes in the nature of the regulation of our businesses, including expiration or discontinuation of, or significant changes to, existing regulatory mechanisms, could require changes to our business planning and management of our businesses and could adversely affect our results of operations, financial position, and liquidity. Failure to obtain adequate rates or regulatory approvals in a timely manner; failure to obtain necessary licenses or permits from regulatory authorities; the impact of new or modified laws, regulations, standards, interpretations, or other legal requirements; or increased compliance costs could adversely affect our results of operations, financial position, and liquidity. The electric and natural gas rates that we are allowed to charge are determined through regulatory proceedings, which are subject to intervention and appeal. Rates are also subject to legislative actions, which are largely outside of our control. Certain events could prevent us from recovering our costs in a timely manner or from earning adequate returns on our investments. The rates that we are allowed to charge for our utility services significantly influence our results of operations, financial position, and liquidity. The electric and natural gas utility industry is highly regulated. The utility rates charged to customers are determined by governmental entities, including the MoPSC, the ICC, and the FERC. Decisions by these entities are influenced by many factors, including the cost of providing service, the prudency of expenditures, the quality of service, regulatory staff knowledge and experience, customer intervention, and economic conditions, as well as social and political views. Decisions made by these governmental entities regarding customer rates are largely outside of our control. We are exposed to regulatory lag and cost disallowances to varying degrees by jurisdiction, which, if unmitigated, could adversely affect our results of operations, financial position, and liquidity. Rate orders are also subject to appeal, which creates additional uncertainty as to the rates that we will ultimately be allowed to charge for our services. From time to time, our regulators may approve trackers, riders, or other recovery mechanisms that allow electric or natural gas rates to be adjusted without a traditional regulatory rate review. These mechanisms could be changed or terminated. Ameren Missouri’s electric and natural gas utility rates and Ameren Illinois’ natural gas utility rates are typically established in regulatory proceedings that take up to 11 months to complete. Ameren Missouri’s electric and natural gas utility rates established in those proceedings are primarily based on historical costs and revenues. Ameren Illinois’ natural gas rates established in those proceedings are based on 20 estimated future costs and revenues. Thus, the rates that we are allowed to charge for utility services may not match our actual costs at any given time. Rates include an allowed return on investments established by the regulator, including a return at the applicable WACC on rate base, and an amount for income taxes based on the currently applicable statutory income tax rates and amortization associated with excess deferred income taxes. Although rate regulation is premised on providing an opportunity to earn a reasonable rate of return on rate base, there can be no assurance that the regulator will determine that our costs were prudently incurred or that the regulatory process will result in rates that will produce full recovery of such costs or provide for an opportunity to earn a reasonable return on those investments. Ameren Missouri and Ameren Illinois, and the utility industry generally, have an increased need for cost recovery, primarily driven by capital investments, which is likely to continue in the future. The resulting increase to the revenue requirement needed to recover such costs and earn a return on investments could result in more frequent regulatory rate reviews and requests for cost recovery mechanisms. Additionally, increasing rates could result in regulatory or legislative actions, as well as competitive or political pressures, all of which could adversely affect our results of operations, financial position, and liquidity. Ameren Illinois expects to use the IEIMA performance-based formula ratemaking framework to establish annual customer rates effective through 2023. Effective for rates beginning in 2024, Ameren Illinois will establish electric distribution rates through either a traditional regulatory rate review or an MYRP. As a result of its participation in the IEIMA performance-based formula ratemaking, Ameren Illinois’ ROE for its electric distribution service through 2023 and its electric energy-efficiency investments is directly correlated to yields on United States Treasury bonds. Additionally, Ameren Illinois is subject to certain performance standards. With respect to its natural gas delivery service business, unless extended, Ameren Illinois’ QIP will expire after December 2023. Ameren Illinois expects to continue to use the current IEIMA performance-based formula ratemaking framework to establish annual customer rates effective through 2023 and reconcile the related revenue requirements through an IEIMA reconciliation. The IETL resulted in changes to the regulatory framework applicable to Ameren Illinois’ electric distribution business by giving Ameren Illinois the option to file an MYRP with the ICC by mid-January 2023, with rates effective beginning in 2024, among other things. Subject to a constructive outcome regarding the ICC’s determination of performance metrics, Ameren Illinois anticipates filing an MYRP for rates effective beginning in 2024. An MYRP would establish rates for a four-year period, and Ameren Illinois has the option to file for an MYRP every four years. For rates effective beginning in 2024, Ameren Illinois will be required to establish future rates through a traditional regulatory rate review or an MYRP with the ICC, which might result in rates that do not produce a full or timely recovery of costs or provide for an adequate return on investments and would expose Ameren Illinois’ electric distribution business to the risks described in the immediately preceding risk factor. By law, Ameren Illinois’ electric distribution revenues are decoupled from sales volumes regardless of the process used to establish electric distribution rates, which ensures that the electric distribution revenues authorized in a regulatory rate review are not affected by changes in sales volumes. Ameren Illinois also has an electric energy-efficiency program rider, which includes a return at the applicable WACC on its program investments, that is subject to performance-based formula ratemaking. The ICC annually reviews Ameren Illinois’ rate filings for reasonableness and prudency. If the ICC were to conclude that Ameren Illinois’ costs were not prudently incurred, the ICC would disallow recovery of such costs. The allowed ROE under the IEIMA and electric energy-efficiency formula ratemaking recovery mechanisms is based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. Therefore, Ameren Illinois’ annual ROE for its electric distribution business is directly correlated to the yields on such bonds, which are outside of Ameren Illinois’ control. 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 $11 million change in Ameren’s and Ameren Illinois’ annual net income, based on Ameren Illinois’ 2022 projected year-end rate base, including electric energy-efficiency investments. Ameren Illinois’ electric distribution business is also subject to performance standards. Failure to achieve the standards would result in a reduction in the company’s allowed ROE calculated under the formula ratemaking recovery mechanisms. The performance standards applicable to electric distribution service under the IEIMA include improvements in service reliability to reduce both the frequency and duration of outages, a reduction in the number of estimated bills, a reduction of consumption from inactive meters, and a reduction in bad debt expense. The allowed ROE for electric distribution service may be decreased for penalties up to 38 basis points in 2022 and up to 10 basis points in 2023 if these performance standards are not met. The allowed ROE on energy-efficiency investments can be increased or decreased up to 200 basis points, depending on the achievement of annual energy savings goals. Any adjustments to the allowed ROE for energy-efficiency investments will depend on annual performance for a historical period relative to energy savings goals. In 2021, 2020, and 2019, there were no performance-related basis point adjustments that materially affected financial results. With respect to the MYRP, the ICC-determined ROE 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. 21 While the ICC has approved a plan for Ameren Illinois to invest approximately $100 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 the future plan program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs. The QIP provides Ameren Illinois with recovery of, and a return on, qualifying natural gas infrastructure investments that are placed in service between regulatory rate reviews. Infrastructure investments under the QIP earn a return at the applicable WACC. Ameren Illinois’ QIP is subject to a rate impact limitation of a cumulative 4% per year since the most recent delivery service rate order, with no single year exceeding 5.5%. If the rate impact limitation was met in a particular year, the amount of rate base causing the QIP rate to exceed the limitation would be exposed to regulatory lag until a year when that amount could be recovered under QIP or is added to rate base as a part of a regulatory rate review. Upon issuance of a natural gas delivery service rate order, QIP rate base is transferred to base rates and the QIP is reset to zero. Without legislative action, the QIP will expire after December 2023. If Ameren Illinois is unable to recover investments under the QIP or there is no other regulatory change, Ameren Illinois will be subject to increased regulatory lag on its natural gas infrastructure investments that are placed in service between regulatory rate reviews, which could adversely affect Ameren’s and Ameren Illinois’ investment plans and results of operations, financial position, and liquidity. As a result of the election to use the PISA, Ameren Missouri’s electric rates are subject to a rate cap. Additionally, Ameren Missouri’s investment plan assumes use of PISA through December 2028, which is subject to MoPSC approval that has not yet been requested. As a result of Ameren Missouri’s election to use the PISA, its rate increases are limited to a 2.85% compound annual growth rate in the average overall customer rate per kilowatthour, based on the electric rates that became effective in April 2017, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 2018 MoPSC order. Both the rate cap and the PISA election are effective through December 2023, unless Ameren Missouri requests and receives MoPSC approval of an extension through December 2028. Increased capital investments and operating costs could cause customer rates to exceed the rate cap. In addition, a decrease in off- system sales, which are included in net energy costs within the FAC, could also contribute to customer rates exceeding the rate cap. Off- system sales are affected by generation availability, which is affected by planned and unplanned outages at Ameren Missouri’s energy centers, curtailment of generation resulting from unfavorable economic conditions, the addition of new generation sources, and retirements of Ameren Missouri’s energy centers, among other things. If rate changes from the FAC or the RESRAM riders would cause rates to temporarily exceed the 2.85% rate cap, the overage would be deferred for future recovery in the next regulatory rate review; however, rates established in such regulatory rate review would be subject to the rate cap. Any deferred overages approved for recovery would be recovered over a period of 20 years following approval of amounts in a regulatory rate review. Excluding customer rates under the MEEIA rider, which are not subject to the rate cap, Ameren Missouri would incur a penalty equal to the amount of deferred overage that would cause customer rates to exceed the 2.85% rate cap. A penalty incurred as the result of exceeding the rate cap could adversely affect Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. Ameren Missouri’s planned capital expenditures of up to $9.2 billion from 2022 through 2026 are based on the assumption of continued constructive regulatory frameworks, including an assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA through December 2028. If Ameren Missouri does not obtain approval to use the PISA through December 2028, it could adversely affect Ameren’s and Ameren Missouri’s investment plans and results of operations, financial position, and liquidity. We are subject to various environmental laws. Significant capital expenditures may be required to achieve and to maintain compliance with these environmental laws. Failure to comply with these laws could result in the closing of facilities, alterations to the manner in which these facilities operate, increased operating costs, delays and increased costs of building new facilities, or exposure to fines and liabilities. 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. Further, we are subject to risks from changing or conflicting interpretations of existing laws, modification to existing laws, new laws, and new or modified permit terms. We are also subject to liability under environmental laws that address the remediation of environmental contamination on property currently or formerly owned by us or by our predecessors, as well as property contaminated by hazardous substances that we generated. Such properties include MGP sites and third-party sites, such as landfills. Additionally, private individuals may seek to enforce environmental laws against us. They could allege injury from exposure to hazardous materials, allege a failure to comply with environmental laws, seek to compel remediation of environmental contamination, or seek to recover damages resulting from that contamination. 22 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. As of December 31, 2021, Ameren Missouri’s coal-fired energy centers represented 10% and 20% of Ameren’s and Ameren Missouri’s rate base, respectively. Clean Air Act regulations that apply to the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO2, particulate matter, NOx, mercury, toxic metals, and acid gases, and CO2 emissions from new power plants. Regulations implementing the Clean Water Act govern both intake and discharges of water 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, these capital expenditures 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 our surface impoundments at Ameren Missouri’s 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 of Ameren Missouri’s energy centers. In January 2011, the United States Department of Justice, on behalf of the EPA, filed a complaint against Ameren Missouri in the United States District Court for the Eastern District of Missouri alleging that in performing projects at its coal-fired Rush Island Energy Center in 2007 and 2010, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. In January 2017, the district court issued a liability ruling against Ameren Missouri and, in September 2019, entered a remedy order. That remedy order included a requirement to install a flue gas desulfurization system at the Rush Island Energy Center, which was upheld through an appeals process by the United States Court of Appeals for the Eighth Circuit in the fourth quarter of 2021. Based on its assessment of available legal, operational and regulatory alternatives, Ameren Missouri has determined not to further appeal the court rulings and, in December 2021, filed a motion with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The district court is under no deadline to issue a ruling revising the remedy order. In January 2022, the MISO completed a preliminary assessment regarding potential impacts of the retirement to the regional electric power system, which indicated transmission upgrades and voltage support would be needed in advance of the retirement to address reliability concerns. In February 2022, Ameren Missouri expects to formally notify the MISO of its intent to retire the Rush Island Energy Center. Upon receipt of the formal notification, the MISO will conduct a final reliability assessment. The MISO must also separately approve the specific upgrades and transmission support required to address reliability concerns noted in the assessment. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center, including potential impacts on the reliability and cost of Ameren Missouri’s service to its customers, Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement, and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. The MoPSC staff is under no deadline to complete this review. As of December 31, 2021, the Rush Island Energy Center had a net plant balance of approximately $0.6 billion and a rate base of approximately $0.4 billion. In addition, Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect 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 of this matter; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. The EPA’s Affordable Clean Energy Rule repealed the Clean Power Plan and replaced it with a new rule that established emission guidelines for states to follow in developing plans to limit CO2 emissions and identified certain efficiency measures as the best system of emission reduction for coal-fired electric generating units. In January 2021, the United States Court of Appeals for the District of Columbia Circuit vacated the Affordable Clean Energy Rule, and ruled that the EPA had the discretion to consider emission reduction measures that include efficiency measures and generation shifting to lower carbon emissions. The United States Supreme Court agreed to review the court of appeals’ ruling and oral arguments will occur in February 2022 with a decision expected by mid-2022. A decision by the United States Supreme Court could impact the EPA’s development of new regulations to address carbon emissions from coal- and natural gas-fired electric generating units. At this time, Ameren Missouri cannot predict the outcome of the legal challenge or future rulemakings. As such, any impact on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri is uncertain. The EPA’s CCR Rule establishes requirements for the management and disposal of CCR from coal-fired power plants and will result in the closure of surface impoundments at Ameren Missouri’s energy centers. In January 2022, Ameren Missouri received notice of a proposed determination by the EPA that it has rejected Ameren Missouri’s requests to extend the timeline for operating certain impoundments located at the Sioux and Meramec energy centers. Compliance with the CCR Rule’s requirements for closure of the impoundments would be required 135 days after the EPA issues a final determination, which Ameren Missouri expects to be issued in the spring of 2022. 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 is in place. Ameren Missouri plans to retire the Meramec Energy Center in 2022, and is accelerating its construction plans to build a CCR Rule-compliant impoundment at the Sioux Energy Center to allow for continued operations. Additionally, Ameren Missouri is seeking a reliability determination from the MISO, which, if granted, would extend the deadline to comply with the requirement to close the impoundments and allow the energy centers to operate. 23 The IETL established emission standards that became effective in September 2021. Ameren Missouri's natural gas-fired energy centers in Illinois will be 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, which could limit the operations of Ameren Missouri's five natural gas-fired energy centers located in the state of Illinois, and will result in the closure of one or more energy centers earlier than anticipated. 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 is reviewing the emission standards and the effect they may have on its generation strategy, including any increases in capital expenditures or operating costs, and changes to the useful lives of the five natural gas-fired energy centers. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect, among other things, the impact of these new emissions standards. Ameren and Ameren Missouri have incurred, and expect to incur, significant costs with respect to environmental compliance and site remediation. New or revised environmental regulations, enforcement initiatives, or legislation could result in a significant increase in capital expenditures and operating costs, decreased revenues, penalties or fines, reduced operations or closure of some of Ameren Missouri’s coal- and natural gas-fired energy centers, which, in turn, could lead to increased liquidity and financing needs, and higher financing costs. Actions required to ensure that Ameren Missouri’s facilities and operations are in compliance with environmental laws could be prohibitively expensive for Ameren Missouri if the costs are not fully recovered through rates. Environmental laws could require Ameren Missouri to close or to alter significantly the operations of its energy centers. If Ameren Missouri requests recovery of capital expenditures and costs for environmental compliance through rates, the MoPSC could deny recovery of all or a portion of these costs, prevent timely recovery, or make changes to the regulatory framework in an effort to minimize rate volatility and customer rate increases. Capital expenditures and costs to comply with future legislation or regulations might result in Ameren Missouri closing coal-fired energy centers earlier than planned. If these costs are not recoverable through base rates or other regulatory mechanisms, it could lead to an impairment of assets and reduced revenues. Any of the foregoing could have an adverse effect on our results of operations, financial positions, and liquidity. We are subject to business and financial risks related to the impact of climate change legislation, regulation, and emission reduction goals. There is increasing concern and activism among various external stakeholders, both nationally and internationally, about climate change, including public concerns about the potential environmental impacts from the combustion of fossil fuels, as well as pressure from public interest groups regarding limiting the use of natural gas. State and federal authorities, including the United States Congress, have considered initiatives to further restrict greenhouse gases to address global climate change. Additionally, international agreements could lead to future federal or state legislation or regulations. In 2015, the United Nations Framework Convention on Climate Change reached consensus among approximately 190 nations on an agreement, known as the Paris Agreement, that establishes a framework for greenhouse gas mitigation actions by all countries, with a goal of holding the increase in global average temperature to below 2 degrees Celsius above pre-industrial levels and an aspiration to limit the increase to 1.5 degrees Celsius. The Biden administration has announced a new policy commitment regarding a reduction in greenhouse gas emissions for the United States, but rulemaking to achieve such reductions has not yet been implemented. Actions taken to implement the Paris Agreement could result in future additional greenhouse gas reduction requirements in the United States. In addition, the Biden administration has announced plans to implement new climate change programs, including potential regulation of greenhouse gas emissions targeting the utility industry. As a result of our diverse fuel portfolio, our emissions of greenhouse gases vary among our energy centers, but coal-fired power plants are significant sources of CO2 emissions. Future federal and state legislation or regulations that mandate limits on the emission of, or impose taxation on, greenhouse gases could result in a significant increase in capital expenditures and operating costs, decreased revenues, penalties or fines, or reduced operations of some of Ameren Missouri’s coal- and natural gas-fired energy centers, which, in turn, could lead to increased liquidity and financing needs, and higher financing costs. Moreover, to the extent Ameren Missouri requests recovery of these costs through rates, its regulators might deny some or all of, or defer timely recovery of, these costs. Excessive costs to comply with future legislation or regulations related to climate change might force Ameren Missouri to close some coal-fired energy centers earlier than planned, which could lead to possible loss on abandonment and reduced revenues. As a result, mandatory limits could have a material adverse impact on Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. Ameren established a goal of achieving net-zero carbon emissions by 2050. Ameren is also targeting a 50% CO2 emission reduction by 2030 and an 85% reduction by 2040 from the 2005 levels. Achievement of these goals is dependent on many factors, including the pace and extent of development and deployment of low- to zero-carbon energy technologies and carbon capture technologies, and the cost of those technologies; natural gas prices; new transmission infrastructure; and constructive energy policies, including those that address investment in energy infrastructure, global climate change, incentives for clean energy technologies, and environmental regulations. Additional factors associated with operational risks for the construction and acquisition of electric and natural gas infrastructure may also affect the achievement of these goals, as further discussed below. The strategy to achieve these goals also relies on continuing to pursue a diverse portfolio including low-carbon and carbon-free resources and energy-efficiency resources; continuing to participate in efforts to help advance the development of technologies such as carbon capture, utilization, and sequestration; the use of hydrogen fuel for electric production and 24 energy storage, next generation nuclear, and large-scale long-cycle battery energy storage; and constructively engaging with legislators, regulators, investors, customers, and other stakeholders to support outcomes leading to a net-zero future. We are subject to federal regulatory compliance and proceedings, which could result in increasing costs and the potential for regulatory penalties and other sanctions. We are subject to FERC regulations, rules, and orders, including standards required by the NERC. As owners and operators of bulk power transmission systems and electric energy centers, we are subject to mandatory NERC reliability standards, including cybersecurity standards. In addition, our natural gas transmission, distribution, and storage facilities systems are subject to PHMSA rules and regulations. Compliance with these reliability standards, rules, and regulations may subject us to higher operating costs and may result in increased capital expenditures. We may also incur higher operating costs to comply with potential new regulations issued by these regulatory bodies. If we were found not to be in compliance with these mandatory NERC reliability standards, PHMSA rules and regulations, or FERC regulations, rules, and orders, we could incur substantial monetary penalties and other sanctions, which could adversely affect our results of operations, financial position, and liquidity. The FERC can impose civil penalties of approximately $1.4 million per violation per day for violation of its regulations, rules, and orders, including mandatory NERC reliability standards. The FERC also conducts audits and reviews of Ameren Missouri’s, Ameren Illinois’, and ATXI’s accounting records to assess the accuracy of their respective formula ratemaking process, and it can require refunds to customers for previously billed amounts, with interest. OPERATIONAL RISKS The construction and acquisition of, and capital improvements to, electric and natural gas utility infrastructure, along with Ameren Missouri’s ability to implement its Smart Energy Plan, which is aligned with its 2020 IRP, involve substantial risks. We expect to make significant capital expenditures to maintain and improve our electric and natural gas utility infrastructure and to comply with existing environmental regulations. 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 from 2022 through 2026. For additional information on these estimates, see Liquidity and Capital Resources – Capital Expenditures in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report. Investments in Ameren’s rate-regulated operations are expected to be recoverable from customers, but they are subject to prudence reviews and are exposed to regulatory lag of varying degrees by jurisdiction. Our ability to complete construction projects successfully within projected estimates, including schedule, performance, and/or cost, and to implement Ameren Missouri’s Smart Energy Plan, which may include acquisition of generation facilities after they are constructed, is contingent upon many factors and subject to substantial risks. These factors include, but are not limited to, the following: project management expertise; escalating costs and/or shortages for labor, materials, and equipment, including changes to tariffs on materials; the ability of suppliers, contractors, and developers to meet contractual commitments timely; changes in the scope and timing of projects; the ability to obtain required regulatory, project, and permit approvals; the ability to obtain necessary rights-of-way, easements, and transmission connections at an acceptable cost in a timely fashion; unsatisfactory performance by the projects when completed; the inability to earn an adequate return on invested capital; the ability to raise capital on reasonable terms; and other events beyond our control, including construction delays due to weather. With respect to the transition of Ameren Missouri’s generation fleet and achievement of the carbon emission reduction targets outlined in the 2020 IRP, factors also include MoPSC approval for the 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; levels of customer participation in the energy-efficiency programs; the cost and commercial availability of wind, solar, and other renewable generation and storage technologies; the ability to qualify for, and use, federal production or investment tax credits; changes in environmental laws or requirements, including those related to carbon emissions; and energy prices and demand. Any of these risks could result in higher costs, the inability to complete anticipated projects, or facility closures, and could adversely affect our results of operations, financial position, and liquidity. Our electric generation, transmission, and distribution facilities are subject to operational risks. Our financial performance depends on the successful operation of electric generation, transmission, and distribution facilities. Operation of electric generation, transmission, and distribution facilities involves many risks, including: • • • • facility shutdowns due to operator error, or a failure of equipment or processes; longer-than-anticipated maintenance outages; failures of equipment that can result in unanticipated liabilities or unplanned outages, such as the unplanned outage resulting from non- nuclear operating issues related to the Callaway Energy Center’s generator that occurred from December 2020 to August 2021; aging infrastructure that may require significant expenditures to operate and maintain; 25 • • • • • • • • • • • • • • • • • • • • an energy center that might not be permitted to continue to operate if pollution control equipment is not installed by prescribed deadlines or does not perform as expected; lack of adequate water required for cooling plant operations; labor disputes; disruptions in the delivery of electricity to our customers; inability to maintain reliability of our electric utility services as coal-fired energy centers are retired and renewable energy generation is placed in service; suppliers and contractors who do not perform as required under their contracts; failure of other operators’ facilities and the effect of that failure on our electric system and customers; inability to comply with regulatory or permit requirements, including those relating to environmental laws; handling, storage, and disposition of CCR; unusual or adverse weather conditions or other natural disasters, including those that may result from climate change, such as severe storms, droughts, floods, tornadoes, earthquakes, icing, sustained high or low temperatures, such as the extremely low temperatures experienced in mid-February 2021, solar flares, and electromagnetic pulses; the level of wind and solar resources; inability to operate wind generation facilities at full capacity resulting from requirements to protect natural resources, including wildlife; the occurrence of catastrophic events such as fires, explosions, acts of sabotage or terrorism, civil unrest, pandemic health events, including the COVID-19 pandemic, or other similar events; accidents that might result in injury or loss of life, extensive property damage, or environmental damage; ineffective vegetation management programs; cybersecurity risks, including loss of operational control of Ameren Missouri’s energy centers and our transmission and distribution systems and loss of data, including sensitive customer, employee, financial, and operating system information, through insider or outsider actions; limitations on amounts of insurance available to cover losses that might arise in connection with operating our electric generation, transmission, and distribution facilities; inability to implement or maintain information systems; failure to keep pace with and the ability to adapt to rapid technological change; and other unanticipated operations and maintenance expenses and liabilities. The foregoing risks could affect the controls and operations of our facilities or impede our ability to meet regulatory requirements, which could increase operating costs, increase our capital requirements and costs, reduce our revenues, or have an adverse effect on our liquidity. Ameren Missouri’s ability to obtain an adequate supply of coal could limit operation of its coal-fired energy centers. Ameren Missouri owns and operates coal-fired energy centers. About 98% of Ameren Missouri’s coal is purchased from the Powder River Basin in Wyoming, which has a limited number of suppliers. Deliveries from the Powder River Basin have occasionally been restricted because of rail congestion, staffing and equipment issues, infrastructure maintenance, derailments, weather, and supplier financial hardship. Coal suppliers in the Powder River Basin are experiencing financial hardship because of a decrease in demand resulting from increased natural gas and renewable energy generation, and the impact of environmental regulations and concerns related to coal-fired generation. These financial hardships have resulted in bankruptcy filings by certain coal suppliers in recent years. As of December 31, 2021, coal inventories at the Sioux and Rush Island energy centers were near targeted levels, and coal inventories at the Labadie Energy Center were below targeted levels due to transportation disruptions in 2021. Ameren Missouri is actively managing inventories at the Meramec Energy Center in preparation for its expected 2022 retirement. However, additional disruptions in the delivery of coal, failure of our coal suppliers to provide adequate quantities or quality of coal, or lack of adequate inventories of coal, including low-sulfur coal used to comply with environmental regulations, could have adverse effects on Ameren Missouri’s electric generation operations. If Ameren Missouri is unable to obtain an adequate supply of coal under existing agreements, it may be required to purchase coal at higher prices or be forced to reduce generation at its coal-fired energy centers, which could adversely affect Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. Ameren Missouri’s ownership and operation of a nuclear energy center creates business, financial, and waste disposal risks. Ameren Missouri’s ownership of the Callaway Energy Center subjects it to risks associated with nuclear generation, including: • • • potential harmful effects on the environment and human health resulting from radiological releases associated with the operation of nuclear facilities and the storage, handling, and disposal of radioactive materials; continued uncertainty regarding the federal government’s plan to permanently store spent nuclear fuel and, as a result, the need to provide for long-term storage of spent nuclear fuel at the Callaway Energy Center; limitations on the amounts and types of insurance available to cover losses that might arise in connection with the Callaway Energy Center or other United States nuclear facilities; 26 • • • • • • • uncertainties about contingencies and retrospective premium assessments relating to claims at the Callaway Energy Center or any other United States nuclear facilities; public and governmental concerns about the safety and adequacy of security at nuclear facilities; limited availability of fuel supply and our reliance on licensed fuel assemblies from the one NRC-licensed supplier of Callaway Energy Center’s assemblies; costly and extended outages for scheduled or unscheduled maintenance and refueling, such as the unplanned outage resulting from non-nuclear operating issues related to the Callaway Energy Center’s generator that occurred from December 2020 to August 2021; uncertainties about the technological and financial aspects of decommissioning nuclear facilities at the end of their licensed lives; the adverse effect of poor market performance and other economic factors on the asset values of nuclear decommissioning trust funds and the corresponding increase, upon MoPSC approval, in customer rates to fund the estimated decommissioning costs; and potential adverse effects of a natural disaster, acts of sabotage or terrorism, including a cyber attack, or any accident leading to a radiological release. The NRC has broad authority under federal law to impose licensing and safety requirements for nuclear facilities. In the event of noncompliance, the NRC has the authority to impose fines or to shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Revised safety requirements promulgated from time to time by the NRC could necessitate substantial capital expenditures at the Callaway Energy Center. In addition, if a serious nuclear incident were to occur, it could adversely affect Ameren’s and Ameren Missouri’s results of operations, financial condition, and liquidity. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation of any domestic nuclear unit and could also cause the NRC to impose additional conditions or requirements on the industry, which could increase costs and result in additional capital expenditures. While the Callaway Energy Center is in compliance with the current NRC standards relating to seismic design and risk, these standards also require Ameren Missouri to address periodic changes to seismic hazard data and evaluation methods for the impact of an earthquake on its Callaway Energy Center due to its proximity to a fault line, which could require seismic risk evaluation updates and installation of additional capital equipment. Our natural gas distribution and storage activities involve numerous risks that may result in accidents and increased operating costs. Inherent in our natural gas distribution and storage activities are a variety of hazards and operating risks, such as leaks, explosions, mechanical problems and cybersecurity risks, which could cause substantial financial losses, including fines and penalties. In addition, these hazards could result in serious injury, loss of human life, significant damage to property, environmental impacts, and impairment of our operations, which in turn could lead us to incur substantial losses. The location of distribution mains and storage facilities near populated areas, including residential areas, business centers, industrial sites, and other public gathering places, could increase the level of damages resulting from these risks. A major domestic incident involving natural gas distribution, and storage systems could result in additional capital expenditures and/or increased operations and maintenance expenses for us and increased regulation of natural gas utilities. The occurrence of any of these events could adversely affect our results of operations, financial position, and liquidity. Significant portions of our electric generation, transmission, and distribution facilities and natural gas transmission and distribution facilities are aging. This aging infrastructure may require significant additional maintenance or replacement. Ameren Missouri could be adversely affected if it is unable to recover the remaining investment, if any, 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. Our aging infrastructure may pose risks to system reliability and expose us to expedited or unplanned significant capital expenditures and operating costs. All of Ameren Missouri’s coal-fired energy centers were constructed prior to 1978, and the Callaway Energy Center began operating in 1984. The age of these energy centers increases the risks of unplanned outages, reduced generation output, and higher maintenance expense. Further, Ameren Missouri would be adversely affected if the MoPSC does not allow recovery of 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. In addition, as discussed above, Ameren Missouri expects the retirement date of its Rush Island Energy Center to be accelerated from the date reflected in depreciation rates approved in the December 2021 MoPSC electric rate order. Aging transmission and distribution facilities are more prone to failure than new facilities, which results in higher maintenance expense and the need to replace these facilities with new infrastructure. Even when the system is properly maintained, its reliability may ultimately deteriorate and negatively affect our ability to serve our customers, which could result in increased costs associated with regulatory oversight. The frequency and duration of customer outages are among the IEIMA performance standards. Any failure to achieve these standards will result in a reduction in Ameren Illinois’ allowed ROE on electric distribution assets. The higher maintenance costs associated with aging infrastructure and capital expenditures for new or replacement infrastructure could cause additional rate volatility for our customers, resistance by our regulators to allow customer rate increases, and/or regulatory lag in some of our jurisdictions, any of which could adversely affect our results of operations, financial position, and liquidity. 27 Energy conservation, energy efficiency, distributed generation, energy storage, technological advances, and other factors could reduce energy demand from our customers. Without a regulatory mechanism to ensure recovery, declines in energy usage could result in an under-recovery of our revenue requirement or an increase in our customer rates, as the revenue requirement would be spread over less sales volumes, which could adversely affect our results of operations, financial position, and liquidity. Such declines could occur due to a number of factors, including: • • • • customer energy-efficiency programs that are designed to reduce energy demand; energy-efficiency efforts by customers not related to our energy-efficiency programs; increased customer use of distributed generation sources, such as solar panels and other technologies, which have become more cost- competitive, with decreasing costs expected in the future, as well as the use of energy storage technologies; and macroeconomic factors resulting in low economic growth or contraction within our service territories, which could reduce energy demand. Decreased use of our generation, transmission, and distribution services might result in stranded costs, which ultimately might not be recovered through rates, and therefore, could lead to an impairment or abandonment of assets. FINANCIAL, ECONOMIC, AND MARKET RISKS Ameren’s holding company structure could limit its ability to pay common stock dividends and to service its debt obligations. Ameren is a holding company; therefore, its primary assets are its investments in the common stock of its subsidiaries, including Ameren Missouri, Ameren Illinois, and ATXI. As a result, Ameren’s ability to pay dividends on its common stock depends on the earnings of its subsidiaries and the ability of its subsidiaries to pay dividends or otherwise transfer funds to Ameren. Similarly, Ameren’s ability to service its debt obligations is dependent upon the earnings of its operating subsidiaries and the distribution of those earnings and other payments, including payments of principal and interest under affiliate indebtedness. The payment of dividends to Ameren by its subsidiaries in turn depends on their results of operations, and other items affecting retained earnings, and available cash. Ameren’s subsidiaries are separate and distinct legal entities and have no obligation, contingent or otherwise, to pay any dividends or make any other distributions (except for payments required pursuant to the terms of affiliate borrowing arrangements and cash payments under the tax allocation agreement) to Ameren. Certain financing agreements, corporate organizational documents, and certain statutory and regulatory requirements may impose restrictions on the ability of Ameren Missouri, Ameren Illinois, and ATXI to transfer funds to Ameren in the form of cash dividends, loans, or advances. Significant increases in prices of commodities, labor, services, materials, and supplies and other costs, including costs associated with our defined benefit retirement and postretirement plans, health care plans, and other employee benefits, could adversely affect our results of operations, financial position, or liquidity. A part of our core strategy focuses on disciplined cost management, including prudently monitoring all of our expenses. However, we have observed and expect future inflationary pressures related to prices of commodities, labor, services, materials, and supplies and other costs, including in the areas of health care and pension costs. These inflationary pressures could impact our ability to control costs, to make substantial investments in our businesses, to recover costs and investments, to earn our allowed ROEs within frameworks established by our regulators, and/or to maintain affordability of our services for our customers. Significant increases in our costs could increase our financing needs and otherwise adversely affect our results of operations, financial position, and liquidity. Related to benefits, Ameren has defined benefit pension plans covering substantially all of its employees and has postretirement benefit plans covering non-union employees hired before October 2015 and union employees hired before January 2020. Assumptions related to future costs, returns on investments, interest rates, timing of employee retirements, and mortality, as well as other actuarial matters, have a significant impact on our customers’ rates and our plan funding requirements. Ameren’s total pension and postretirement benefit plans were overfunded by $717 million as of December 31, 2021. Ameren expects to fund its pension plans at a level equal to the greater of the pension cost or the legally required minimum contribution. Based on its assumptions at December 31, 2021, its investment performance in 2021, and its pension funding policy, Ameren, Ameren Missouri, and Ameren Illinois do not expect to make material contributions in the aggregate over the next five years. These estimated contributions may change based on actual investment performance, changes in interest rates, changes in our assumptions, changes in government regulations, and any voluntary contributions. In addition to the costs of our pension plans, the costs of providing health care benefits to our employees and retirees have increased in recent years. We believe that our employee benefit costs, including costs of health care plans for our employees and former employees, will continue to rise. Future legislative changes related to health care could also significantly change our benefit programs and costs. 28 GENERAL RISKS Our results of operations, financial position, and liquidity have been and are expected to continue to be adversely affected by the international public health emergency associated with the COVID-19 pandemic. 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 2021, compared to 2020, and total sales volume levels were more comparable to pre-pandemic levels, there has been a shift in sales volumes by customer class, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect of the 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. In addition, although restrictions on social activities and nonessential businesses implemented in our service territories in 2020 have been relaxed, additional restrictions may be imposed in the future. As a result of the COVID-19 pandemic, economic activity has been disrupted in the service territories of Ameren Missouri and Ameren Illinois. The COVID-19 pandemic could continue to affect total electric sales volumes and sales by customer class. Pursuant to the PISA, Ameren Missouri’s electric rates are limited to a 2.85% rate cap. Long-term declines in sales volumes, along with increased capital investments and operating costs, could result in Ameren Missouri’s inability to recover amounts exceeding the rate cap. While the revenues from Ameren Illinois’ electric distribution business, residential and small nonresidential customers of Ameren Illinois’ natural gas distribution business, and Ameren Illinois’ and ATXI’s 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. Our customers’ payment for our services has been impacted by the COVID-19 pandemic, resulting in a decrease to cash from operations. For most of the period from March 2020 through June 2021, the ICC limited disconnection activities and late fees for customer nonpayment to varying degrees based on customer class. A March 2021 ICC order also required Ameren Illinois to offer deferred payment arrangements extending to 18 months to all residential customers through June 2021. 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. In addition, suppliers and contractors may not perform as provided under their contracts. This could cause delays in construction projects, or the performance of necessary maintenance to our electric and natural gas infrastructure, which could lead to failures of equipment that can result in unanticipated liabilities or unplanned outages. Delays in our construction projects could also result in reduced planned capital expenditures and decreased rate base growth. Also, our businesses depend on skilled professional and technical employees. Our operations could be adversely affected if a large portion of our employees contracted COVID-19 or became quarantined at the same time. This could lead to facility shutdowns and disruptions in the delivery of electricity and natural gas to our customers. In addition, remote working arrangements increase our data security risks, including loss of data related to sensitive customer, employee, financial, and operating system information, through insider or outsider actions. Further, compliance with any future vaccine mandates associated with COVID-19 may result in labor shortages, including shortages in skilled professional and technical labor, supply chain disruptions, delays in contractors’ performance or completion of work, and/or increased costs for us, our contractors, or our suppliers. Ameren cannot predict the extent or duration of the COVID-19 pandemic or its effects on the global, national, or local economy, the capital markets, or its customers, suppliers, business continuity plans, results of operations, financial position, liquidity, planned rate base growth, or sales volumes. Customers’, investors’, legislators’, and regulators’ opinions of us are affected by many factors, including system reliability, implementation of our strategic plan, protection of customer information, rates, media coverage, and ESG practices, as well as actions by other utility companies. Negative opinions developed by customers, investors, legislators, or regulators could harm our reputation. Our results are influenced by the expectations of our customers, investors, legislators, and regulators. Those expectations are based, in part, on the reliability and affordability of our utility services. Service interruptions and facility shutdowns can occur due to failures of equipment as a result of severe or destructive weather or other causes. The ability of Ameren Missouri and Ameren Illinois to respond promptly to such failures can affect customer satisfaction. In addition to system reliability issues, the success of modernization efforts, our ability to safeguard sensitive customer information and protect our systems from cyber attacks, and other actions can affect customer satisfaction. The level of rates, the timing and magnitude of rate increases, and the volatility of rates can also affect customer satisfaction. 29 Our ability to successfully execute our strategic plan, including the transition of Ameren Missouri’s generation fleet and achievement of the carbon emission reduction targets outlined in the 2020 IRP, may affect customers’, investors’, legislators’, and regulators’ opinions and actions. Additionally, negative perceptions or publicity resulting from increasing scrutiny of ESG practices could negatively impact our reputation, investment in our common stock, or our access to capital markets. Customers’, investors’, legislators’, and regulators’ opinions of us can also be affected by media coverage, including social media, which may include information, whether factual or not, that damages our brand and reputation. If customers, investors, legislators, or regulators have or develop a negative opinion of us and our utility services, this could result in increased costs associated with regulatory oversight and could affect the ROEs we are allowed to earn, as well as the access to, and the cost of, capital. Additionally, negative opinions about us or other utility companies could make it more difficult for our businesses to achieve favorable legislative or regulatory outcomes. Negative opinions could also result in sales volume reductions or increased use of distributed generation by our customers. Any of these consequences could adversely affect our results of operations, financial position, and liquidity. We are subject to employee work force factors that could adversely affect our operations. Our businesses depend upon our ability to employ and retain key officers and other skilled professional and technical employees. Certain specialized knowledge that focuses on skilled-craft and STEM-related disciplines is required to construct and operate generation, transmission, and distribution assets. Further, a significant portion of our work force is nearing retirement. As of December 31, 2021, approximately 26%, 27%, and 25% of Ameren’s, Ameren Missouri’s, and Ameren Illinois’ total employees were 55 years old or older, respectively. We are also party to collective bargaining agreements that collectively represent about 48%, 58%, and 55% of Ameren’s, Ameren Missouri’s and Ameren Illinois’ total employees, respectively. All of the Ameren Missouri collective bargaining unit contracts expire in 2022. The Ameren Illinois collective bargaining unit contracts expire in 2022 and 2023, which cover 92% and 8% of represented employees, respectively. Due to the COVID-19 pandemic, a large portion of our non-field employees have been primarily working from home since March 2020. While our workforce has largely been stable, we experienced an increase in our attrition rate in 2021. Certain events, such as significant delays in finding appropriate replacement talent, inadequately trained replacement employees, a mismatch of skill sets to future needs, any work stoppage experienced in connection with negotiations of collective bargaining agreements, or challenges with transitioning working arrangements, could adversely affect our operations. Our operations are subject to acts of terrorism, cyber attacks, and other intentionally disruptive acts. Like other electric and natural gas utilities, our energy centers, fuel storage facilities, transmission and distribution facilities, and enterprise information systems may be affected by malicious acts, terrorist activities and other intentionally disruptive acts, including cyber attacks, which could disrupt our ability to produce or distribute our energy products. There have been attacks in the industry on energy infrastructure, such as substations and related assets, in the past, and there may be more attacks in the future as technology becomes more prevalent in energy infrastructure and the threat landscape continues to expand. Any such incident could limit our ability to generate, purchase, or transmit power or natural gas and could have significant regional economic consequences. Any such disruption could result in a significant decrease in revenues, a significant increase in costs including those for repair, or adversely affect economic activity in our service territory which, in turn, could adversely affect our results of operations, financial position, and liquidity. There has been an increase in the number and sophistication of physical and cyber attacks across all industries worldwide. Cyber attacks could include viruses, malicious or destructive code, phishing attacks, denial of service attacks, ransomware and other ransom-based attacks, improper access by third parties, attacks on email systems, and attacks leading to data loss, operational control, or exploitation of vulnerabilities specific to internally developed systems or to those provided and/or maintained by our suppliers, among various other security breaches. A security breach at our physical assets or in our information systems could affect the reliability of the transmission and distribution system, disrupt electric generation, including nuclear generation, and/or subject us to financial harm resulting from theft or the inappropriate release or destruction of certain types of information, including sensitive customer, employee, financial, and operating system information. Many of our suppliers, vendors, contractors, and information technology providers have access to systems that support our operations and maintain customer and employee data. A breach of these third-party systems could adversely affect our business as if it was a breach of our own system. If a significant breach occurred, our reputation could be adversely affected, customer confidence could be diminished, and/or we could be subject to increased costs associated with regulatory oversight, fines or legal claims, any of which could result in a significant decrease in revenues or significant costs for remedying the impacts of such a breach. Our generation, transmission, and distribution systems are part of an interconnected grid. Therefore, a disruption caused by a cyber incident at another utility, electric generator, RTO, or commodity supplier could also adversely affect our businesses. Insurance might not be adequate to cover losses that arise in connection with these events. In addition, new regulations could require changes in our security measures and result in increased costs. The occurrence of any of these events could adversely affect our results of operations, financial position, and liquidity. 30 Our businesses are dependent on our ability to access the capital markets successfully. We might not have access to sufficient capital in the amounts and at the times needed, as well as on reasonable terms. We rely on the issuance of short-term and long-term debt and equity as significant sources of liquidity and funding for capital requirements not satisfied by our operating cash flow, as well as to refinance existing long-term debt. The inability to raise debt or equity capital on reasonable terms, or at all, could negatively affect our ability to maintain or to expand our businesses. Events beyond our control, such as depressed economic conditions, the COVID-19 pandemic, or extreme volatility in the debt, equity, or credit markets, might create uncertainty that could increase our cost of capital or impair or eliminate our ability to access the debt, equity, or credit markets, including our ability to draw on bank credit facilities. Any adverse change in our credit ratings could reduce access to capital and trigger collateral postings and prepayments. Such changes could also increase the cost of borrowing and the costs of fuel, power, and natural gas supply, among other things, which could adversely affect our results of operations, financial position, and liquidity. ITEM 1B. UNRESOLVED STAFF COMMENTS None. 31 ITEM 2. PROPERTIES For information on our principal properties, see the energy center and in-service utility-related properties tables below. See also Liquidity and Capital Resources and Regulatory Matters in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report for a discussion of planned additions. See also Note 5 – Long-term Debt and Equity Financings and Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. The following table shows the anticipated capability of Ameren Missouri’s energy centers at the time of Ameren Missouri’s expected 2022 peak summer electrical demand for all energy centers owned as of December 31, 2021: Primary Fuel Source Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pumped-storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wind . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total wind . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Oil (CTs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total oil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Methane gas (CT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Solar . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total solar . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren and Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . Energy Center Labadie(b) Rush Island(c) Sioux(d) Meramec(d) Callaway(e) Osage(e) Keokuk Location Franklin County, Missouri Jefferson County, Missouri St. Charles County, Missouri St. Louis County, Missouri Callaway County, Missouri Lakeside, Missouri Keokuk, Iowa Taum Sauk(e) High Prairie Renewable Reynolds County, Missouri Adair and Schuyler Counties, Missouri Atchison Renewable Atchison County, Missouri Audrain(f) Venice(g) Goose Creek(g) Pinckneyville(g) Raccoon Creek(g) Meramec(d) Kinmundy(g) Peno Creek(f) Fairgrounds(d) Mexico(d) Moberly(d) Moreau(d) Audrain County, Missouri Venice, Illinois Piatt County, Illinois Pinckneyville, Illinois Clay County, Illinois St. Louis County, Missouri Kinmundy, Illinois Bowling Green, Missouri Jefferson City, Missouri Mexico, Missouri Moberly, Missouri Jefferson City, Missouri Maryland Heights Maryland Heights, Missouri O’Fallon Lambert BJC South St. Louis O’Fallon, Missouri St. Louis County, Missouri St. Louis, Missouri St. Louis, Missouri Net Kilowatt Capability(a) 2,372,000 1,178,000 972,000 510,000 5,032,000 1,194,000 235,000 148,000 383,000 440,000 400,000 298,800 698,800 616,000 489,000 444,000 316,000 308,000 226,000 210,000 172,000 2,781,000 55,000 55,000 55,000 55,000 220,000 9,000 4,500 900 1,600 200 7,200 10,765,000 (a) (b) (c) (d) (e) (f) (g) Net kilowatt capability, except for wind and solar generating facilities, is the generating capacity available for dispatch from the energy center into the electric transmission grid. Capability for wind and solar generating facilities represents nameplate capacity. This capacity is only attainable when wind/solar conditions are sufficiently available. The on-demand capability for wind and solar units is zero. The Labadie Energy Center is scheduled to retire 1,186,000 kilowatts by 2036 and 1,186,000 kilowatts by 2042. The Rush Island Energy Center was scheduled to retire by 2039 as noted in the 2020 IRP. However, changes to the retirement date are subject to a final judgment to be issued by the United States District Court for the Eastern District of Missouri regarding a September 2019 remedy order. For additional information, see Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. The Sioux and Meramec energy centers are scheduled to retire by 2028 and 2022, respectively. The Fairgrounds, Mexico, Moberly, and Moreau energy centers are scheduled to be retired by 2026 as noted in the 2020 IRP. The operating licenses for the Callaway, Osage, and Taum Sauk energy centers expire in 2044, 2047, and 2044, respectively. There are economic development arrangements applicable to these CTs, as discussed below. See Illinois Emissions Standards in Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. 32 The following table presents in-service electric and natural gas utility-related properties for Ameren Missouri and Ameren Illinois as of December 31, 2021: Circuit miles of electric transmission lines(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Circuit miles of electric distribution lines . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Percentage of circuit miles of electric distribution lines underground . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miles of natural gas transmission and distribution mains . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Underground natural gas storage fields . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total working capacity of underground natural gas storage fields in billion cubic feet . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) ATXI owns 545 miles of transmission lines not reflected in this table. Our other properties include office buildings, warehouses, garages, and repair shops. Ameren Missouri 3,109 33,656 Ameren Illinois 4,659 45,890 24 % 16 % 3,480 — — 18,620 12 24 With only a few exceptions, we have fee title to all principal energy centers and other units of property material to the operation of our businesses, and to the real property on which such facilities are located (subject to mortgage liens securing our outstanding first mortgage bonds and to certain permitted liens and judgment liens). The exceptions are as follows: • • Certain property is situated on lands occupied under leases, easements, franchises, licenses, or permits. That property includes a portion of Ameren Missouri’s Osage Energy Center reservoir; certain facilities at Ameren Missouri’s Sioux Energy Center; most of Ameren Missouri’s High Prairie Renewable, Atchison Renewable, Peno Creek CT and Audrain CT energy centers; Ameren Missouri’s Maryland Heights, Lambert, and BJC energy centers; certain substations; and most transmission and distribution lines and natural gas mains. The United States or the state of Missouri may own or may have paramount rights with respect to certain lands lying in the bed of the Osage River or located between the inner and outer harbor lines of the Mississippi River on which certain of Ameren Missouri’s energy centers and other properties are located. The United States, the state of Illinois, the state of Iowa, or the city of Keokuk, Iowa, may own or may have paramount rights with respect to certain lands lying in the bed of the Mississippi River on which a portion of Ameren Missouri’s Keokuk Energy Center is located. Substantially all of the properties and plant of Ameren Missouri and Ameren Illinois are subject to the liens of the indentures securing their mortgage bonds. Ameren Missouri has conveyed most of its Peno Creek CT Energy Center to the city of Bowling Green, Missouri through December 2022. Ameren Missouri has rights and obligations as the operator of the energy center under a long-term agreement with the city of Bowling Green. Under the terms of this agreement, Ameren Missouri is responsible for all operation and maintenance for the energy center. Ownership of the energy center will transfer to Ameren Missouri at the expiration of the agreement, at which time the property, plant, and equipment will become subject to the lien of the Ameren Missouri mortgage bond indenture. Ameren Missouri operates a CT energy center located in Audrain County, Missouri. Ameren Missouri has rights and obligations as the operator of the energy center under a long-term agreement with Audrain County. Under the terms of this agreement, Ameren Missouri is responsible for all operation and maintenance for the energy center. The agreement will expire in December 2023. Ownership of the energy center will transfer to Ameren Missouri at the expiration of the agreement, at which time the property, plant, and equipment will become subject to the lien of the Ameren Missouri mortgage bond indenture. ITEM 3. LEGAL PROCEEDINGS We are involved in legal and administrative proceedings before various courts and agencies with respect to matters that arise in the ordinary course of business, some of which involve substantial amounts of money. We believe that the final disposition of these proceedings, except as otherwise disclosed in this report, will not have a material adverse effect on our results of operations, financial position, or liquidity. Risk of loss is mitigated, in some cases, by insurance or contractual or statutory indemnification. We believe that we have established appropriate reserves for potential losses. For additional information on material legal and administrative proceedings, see Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, and Note 14 – Commitments and Contingencies under Part II, Item 8, of this report. Pursuant to Item 103(c)(3)(iii) of Regulation S-K, our policy is to disclose environmental proceedings to which a governmental entity is a party if we reasonably believe such proceedings will result in monetary sanctions of $1 million or more. ITEM 4. MINE SAFETY DISCLOSURES Not applicable. 33 INFORMATION ABOUT OUR EXECUTIVE OFFICERS: The executive officers of the Ameren Companies, including major subsidiaries, are listed below, along with their ages as of December 31, 2021, all their positions and offices held with the Ameren Companies as of February 22, 2022, and their tenures as officers, and their titles for at least the last five years. AMEREN CORPORATION: Name Age Positions Period Warner L. Baxter............ Martin J. Lyons, Jr. ......... 60 Executive Chairman; Ameren .......................................................... January 2022 – Present Chairman, President, and Chief Executive Officer; Ameren................ 2014(a) – January 2022 55 President and Chief Executive Officer; Ameren................................. January 2022 – Present Michael L. Moehn........... Chairman and President; Ameren Missouri....................................... December 2019 – January 2022 Chairman and President; Ameren Services ...................................... March 2016 – December 2019 Executive Vice President and Chief Financial Officer; Ameren ........... January 2013 – December 2019 52 Executive Vice President and Chief Financial Officer; Ameren ........... December 2019 – Present Chairman and President; Ameren Services ...................................... December 2019 – Present Chairman and President; Ameren Missouri....................................... April 2014 – December 2019 Chonda J. Nwamu.......... 50 Senior Vice President, General Counsel, and Secretary; Ameren ....... August 2019 – Present Senior Vice President and Deputy General Counsel; Ameren Services ........................................................................................ Vice President and Deputy General Counsel; Ameren Services ......... September 2016 – January 2019 January 2019 – August 2019 Theresa A. Shaw............ 49 Senior Vice President, Finance, and Chief Accounting Officer; August 2021 – Present Ameren ......................................................................................... Senior Vice President, Regulatory Affairs and Financial Services; Ameren Illinois ............................................................................... September 2019 – August 2021 Vice President, Regulatory Affairs and Financial Services; Ameren Illinois ........................................................................................... Vice President, Internal Audit; Ameren ............................................. June 2014 – July 2018 July 2018 – August 2019 (a) Elected President of Ameren in February 2014, Chief Executive Officer of Ameren in April 2014, and Chairman of Ameren in July 2014. 34 SUBSIDIARIES: Name Age Positions Period Bhavani Amirthalingam ... 46 Senior Vice President and Chief Digital Information Officer; Ameren March 2018(a) – Present Services ........................................................................................ Mark C. Birk................... 57 Chairman and President; Ameren Missouri....................................... January 2022 – Present Senior Vice President, Customer and Power Operations; Ameren Missouri ........................................................................................ Senior Vice President, Customer Operations; Ameren Missouri.......... January 2017 – October 2017 Senior Vice President, Corporate Safety, Planning and Operations Oversight; Ameren Services............................................................ October 2017 – January 2022 April 2015 – January 2017 Fadi M. Diya .................. Mary P. Heger................ 59 Senior Vice President and Chief Nuclear Officer; Ameren Missouri ..... January 2014 – Present 65 Senior Vice President, Customer Experience; Ameren Illinois ............ February 2019 – Present Mark C. Lindgren............ Senior Vice President and Chief Information Officer; Ameren Services ........................................................................................ 54 Senior Vice President, Corporate Communications, and Chief Human Resources Officer; Ameren Services................................................ September 2015 – February 2019 September 2015 – Present Richard J. Mark.............. Shawn E. Schukar.......... 66 Chairman and President; Ameren Illinois.......................................... June 2012 – Present 60 Chairman and President; ATXI ........................................................ May 2017 – Present Senior Vice President, Transmission Operations, Construction and Project Management; ATXI ............................................................. December 2013 – May 2017 (a) Bhavani Amirthalingam served as the Chief Information Officer and Vice President North America for Schneider Electric SE from January 2015 to March 2018. Officers are generally elected or appointed annually by the respective board of directors of each company, following the election of board members at the annual meetings of shareholders. No special arrangement or understanding exists between any of the above-named executive officers and the Ameren Companies nor, to our knowledge, with any other person or persons pursuant to which any executive officer was selected as an officer. There are no family relationships among the executive officers or between any executive officers and any directors of the Ameren Companies. Except as noted, the above-named executive officers have been employed by an Ameren company for more than five years in executive or management positions. 35 PART II ITEM 5. MARKET FOR REGISTRANTS’ COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASE OF EQUITY SECURITIES Ameren’s common stock is listed on the NYSE (ticker symbol: AEE). Ameren common shareholders of record totaled 40,340 on January 31, 2022. There is no trading market for the common stock of Ameren Missouri and Ameren Illinois. Ameren holds all outstanding common stock of Ameren Missouri and Ameren Illinois. Purchases of Equity Securities Ameren Corporation, Ameren Missouri, and Ameren Illinois did not purchase any equity securities reportable under Item 703 of Regulation S-K during the period from October 1, 2021, to December 31, 2021. Performance Graph The following graph shows Ameren’s cumulative TSR during the five years ended December 31, 2021. The graph also shows the cumulative total returns of the S&P 500 Index, S&P 500 Utility Index, and the Philadelphia Utility Index. The S&P 500 Utility Index and the Philadelphia Utility Index are market capitalization-weighted indices of U.S. public utility companies. The comparison assumes that $100 was invested on December 31, 2016, in Ameren common stock and in each of the indices shown and that all of the dividends were reinvested. Comparison of Five-Year Cumulative Return $225 $200 $175 $150 $125 $100 2016 2017 2018 2019 2020 2021 Ameren (AEE) S&P 500 Index S&P 500 Utility Index Philadelphia Utility Index 36 December 31, Ameren (AEE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ S&P 500 Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S&P 500 Utility Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Philadelphia Utility Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2016 100.00 100.00 100.00 100.00 $ 2017 115.96 121.83 112.11 112.82 $ 2018 132.17 116.49 116.72 116.79 $ 2019 159.69 153.18 147.47 148.11 $ 2020 166.51 181.36 148.18 152.14 $ 2021 194.96 233.43 174.36 179.90 Ameren management cautions that the stock price performance shown above should not be considered indicative of future stock price performance. ITEM 6. (RESERVED) ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS Ameren, headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Below is a summary description of Ameren’s principal subsidiaries – Ameren Missouri, Ameren Illinois, and ATXI. Ameren also has other subsidiaries that conduct other activities, such as providing shared services. A more detailed description can be found in Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. • • • Ameren Missouri operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri. Ameren Illinois operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois. ATXI operates a FERC rate-regulated electric transmission business in the MISO. Ameren has four segments: Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Transmission. The Ameren Missouri segment includes all of the operations of Ameren Missouri. Ameren Illinois Electric Distribution consists of the electric distribution business of Ameren Illinois. Ameren Illinois Natural Gas consists of the natural gas business of Ameren Illinois. Ameren Transmission primarily consists of the aggregated electric transmission businesses of Ameren Illinois and ATXI. See Note 16 – Segment Information under Part II, Item 8, of this report for further discussion of Ameren’s and Ameren Illinois’ segments. Ameren’s financial statements are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been eliminated, except as disclosed in Note 13 – Related-party Transactions under Part II, Item 8, of this report. Ameren Missouri and Ameren Illinois have no subsidiaries. All tabular and graphical dollar amounts are in millions, unless otherwise indicated. The following discussion should be read in conjunction with the financial statements contained in this Form 10-K. We intend for this discussion to provide the reader with information that will assist in understanding our financial statements, the changes in certain key items in those financial statements, and the primary factors that accounted for those changes, as well as how certain accounting principles affect our financial statements. The discussion also provides information about the financial results of our business segments to provide a better understanding of how those segments and their results affect the financial condition and results of operations of Ameren as a whole. Discussion regarding our financial condition and results of operations for the year ended December 31, 2019, including comparisons with the year ended December 31, 2020, is included in Item 7 of our Form 10-K for the year ended December 31, 2020, filed with the SEC on February 22, 2021. In addition to presenting results of operations and earnings amounts in total, we present certain information in cents per diluted share. These amounts reflect factors that directly affect Ameren’s earnings. We believe this per diluted share information helps readers to understand the impact of these factors on Ameren’s earnings per diluted share. 37 OVERVIEW Our core strategy is driven by the following three pillars: Investing in and operating our utilities in a manner consistent with existing regulatory frameworks Enhancing regulatory frameworks and advocating for responsible energy and economic policies We seek to earn competitive returns on investments in our businesses. Accordingly, we remain focused on disciplined cost management and strategic capital allocation. We align our overall spending, both operating and capital, with economic conditions and with the frameworks established by our regulators, to create and capitalize on investment opportunities for the benefit of our customers and shareholders. We focus on minimizing the gap between allowed and earned ROEs and allocating capital resources to business opportunities that we expect will provide the most benefit to our customers and offer the most attractive risk-adjusted return potential. We seek to partner with our stakeholders, including our customers, regulators, federal and state legislators, and RTOs, to enhance our regulatory frameworks and advocate for responsible energy and economic policies for the benefit of our customers and shareholders. We believe constructive regulatory frameworks for investment exist at all of our business segments. Accordingly, we expect to earn competitive returns on investments in our businesses and realize timely recovery of our costs in the coming years with the benefits accruing to both customers and shareholders. Rate Base ($ in billions)(a) Constructive Regulatory Frameworks(c) Creating and capitalizing on opportunities for investment for the benefit of our customers and shareholders We seek to make prudent investments that benefit our customers. The goal of these investments is to maintain and enhance the reliability of our services, develop cleaner sources of energy, create economic development opportunities in our region, and provide customers with more options and greater control over their energy usage, among other things. By prudently investing in our businesses, we believe that we deliver superior value to both customers and shareholders. Improved Reliability(f) Segment Regulatory Framework Ameren Transmission Formula ratemaking Allowed ROE of 10.52% Ameren Illinois Natural Gas Future test year ratemaking and QIP, PGA, VBA Allowed ROE of 9.67% Ameren Illinois Electric Distribution Ameren Missouri Formula ratemaking Allowed ROE of 30-year U.S. Treasury + 5.8%(d) Historical test year ratemaking and PISA, RESRAM, FAC, MEEIA, PGA Allowed ROE is not specified(e) Customer Rates, (¢/KWH)(g) TSR 2016-2021(h) (a) (b) (c) (d) (e) (f) (g) (h) Reflects year-end rate base except for Ameren Transmission, which is average rate base. Compound annual growth rate. As of January 2022 for Ameren Transmission, Ameren Illinois Natural Gas, and Ameren Illinois Electric Distribution. As of February 28, 2022, for Ameren Missouri. Allowed ROE is subject to performance standards as discussed in Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. Allowed ROE applicable to electric and natural gas delivery service. As measured by the System Average Interruption Frequency Index (SAIFI). Represents the average of Ameren Missouri and Ameren Illinois. Average residential electric prices. Source: Edison Electric Institute, “Typical Bills and Average Rates Report” for the 12 months ended June 30, 2021. Ameren management cautions that the stock price performance shown above should not be considered indicative of future stock price performance. Key announcements, updates, and regulatory outcomes 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 2021, compared to 2020, and total sales volume levels were more comparable to pre-pandemic levels, there has been a shift in sales volumes by customer class, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect of the 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 Significant Accounting Policies and Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report, and Results of Operations, Liquidity and Capital Resources, and Outlook sections below. In addition, for information regarding Ameren Illinois’ suspension and 38 subsequent reinstatement of customer disconnection activities and late fee charges for nonpayment, see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. Due to extremely cold winter weather 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 long-term debt issuances. Ameren Missouri and Ameren Illinois have cost recovery mechanisms in place that provide recovery of the higher natural gas costs and purchased power from customers over periods of time established under the applicable mechanisms. In January 2021, Ameren Missouri acquired a 300-MW wind generation project located in northwestern Missouri. As of June 30, 2021, Ameren Missouri had placed the project in service as the Atchison Renewable Energy Center. The purchase price of the energy center was approximately $500 million, including an immaterial amount of transaction costs. In December 2020, Ameren Missouri acquired a 400-MW wind generation project located in northeastern Missouri for approximately $615 million, and placed the assets in service as the High Prairie Renewable Energy Center. The purchase price included $564 million of cash, a deferred purchase price obligation withheld as credit support in relation to certain potential claims, contingent consideration, and transaction costs. Both renewable energy centers support Ameren Missouri’s compliance with the Missouri renewable energy standard. During its return to full power after the completion of the last refueling and maintenance outage in late December 2020, the Callaway Energy Center experienced a non-nuclear operating issue related to its generator. After replacement of certain key components of the generator, the energy center returned to service in early August 2021. The cost of generator repairs was approximately $60 million, which was largely capital expenditures. See Note 9 – Callaway Energy Center under Part II, Item 8, of this report for additional information. In August 2021, the United States Court of Appeals for the Eighth Circuit issued a decision that affirmed the United States District Court for the Eastern District of Missouri’s January 2017 liability ruling and the district court’s September 2019 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 has determined not to further appeal the court rulings and, in December 2021, filed a motion with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The district court is under no deadline to issue a ruling revising the remedy order. In January 2022, the MISO completed a preliminary assessment regarding potential impacts of the retirement to the regional electric power system, which indicated transmission upgrades and voltage support would be needed in advance of the retirement to address reliability concerns. In February 2022, Ameren Missouri expects to formally notify the MISO of its intent to retire the Rush Island Energy Center. Upon receipt of the formal notification, the MISO will conduct a final reliability assessment. The MISO must also separately approve the specific upgrades and transmission support required to address reliability concerns noted in the assessment. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center, including potential impacts on the reliability and cost of Ameren Missouri’s service to its customers, Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement, and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. 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 that became effective in August 2021. See Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for additional information. In September 2021, the MoPSC issued an order approving Ameren Missouri’s energy savings results for the second year of the MEEIA 2019 program. As a result of this order, and in accordance with revenue recognition guidance, Ameren Missouri recognized revenues of $9 million in 2021. In December 2021, the MoPSC issued orders in Ameren Missouri’s 2021 electric service and natural gas delivery service regulatory rate reviews. The orders will result in increases of $220 million and $5 million to Ameren Missouri’s annual revenue requirements for electric retail service and natural gas delivery service, respectively. The electric revenue requirement increase is based on a rate base of $10.2 billion, infrastructure investments as of September 30, 2021, and a change in the depreciable lives of the Sioux and Rush Island energy centers’ assets consistent with Ameren Missouri’s 2020 IRP. The electric order did not specify an ROE, but specified that Ameren Missouri’s September 30, 2021 capital structure, which was composed of 51.97% common equity, will be used in the PISA and RESRAM. The electric rate order provides for the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable energy standard costs that the MoPSC previously authorized in earlier electric rate orders. It also establishes a five-year recovery period for $61 million of certain costs associated with the Meramec Energy Center, which is expected to be retired in 2022. The orders also approved for recovery $9 million of certain costs and forgone customer late fee and reconnection fee revenues resulting from the COVID-19 pandemic that were accumulated pursuant to March 2021 MoPSC orders. The new electric and natural gas rates will become effective on February 28, 2022. 39 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 Missouri’s electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $8.4 billion over the five-year period from 2022 through 2026, with expenditures largely recoverable under the PISA and the RESRAM. The planned investments in 2024 through 2026 are based on the assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA from December 2023 to December 2028. In March 2021, the ICC issued an order approving Ameren Illinois’ requested tariff to reconcile its electric distribution service revenue requirement once Ameren Illinois ceases to update customer rates under performance-based formula ratemaking. The last update under such ratemaking is anticipated to be for 2023 customer rates. The tariff would allow Ameren Illinois to reconcile its revenue requirement for customer rates established for 2022 and 2023. To utilize the reconciliation, Ameren Illinois is required to file a request to update its electric distribution service rates through either a traditional regulatory rate review, which may be based on a future test year and would reflect a proposed ROE subject to ICC approval, or through the filing of an MYRP, which Ameren Illinois expects to file for rates effective beginning in 2024 pursuant to the IETL as described below. The rate update request would need to be filed by mid-January 2023. Pursuant to the order, Ameren Illinois’ 2022 and 2023 revenues would reflect each year’s actual recoverable costs, year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The revenue requirement reconciliation adjustment would be collected from, or refunded to, customers within two years from the end of the reconciled year. In September 2021, the IETL was enacted, which resulted in changes to the regulatory framework applicable to Ameren Illinois’ electric distribution business, among other things. The IETL allows Ameren Illinois to file an MYRP with the ICC by mid-January 2023, with rates effective beginning in 2024. Subject to a constructive outcome regarding the ICC’s determination of performance metrics, Ameren Illinois anticipates filing an MYRP by mid-January 2023 to establish rates for 2024. Under the MYRP, the ICC would approve base rates for electric distribution service to be charged to customers for each calendar year of a four-year period, based on each year's forecasted recoverable costs, an ICC-determined ROE applied to each calendar year of the four-year period, and a common equity ratio of up to 50% being deemed prudent and reasonable by law, with a higher equity ratio requiring specific ICC approval. The approved ROE would be subject to adjustment 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. The MYRP would also allow Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis, subject to an aggregate reconciliation cap of 105% of the annual revenue requirement approved by the ICC. Certain variations from forecasted costs and costs recovered through riders outside of base rates would be excluded from the reconciliation cap. Electric distribution service revenues would continue to be decoupled from sales volumes under an MYRP. If Ameren 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. In July 2021, the ICC issued an order approving Ameren Illinois’ energy-efficiency plan that includes annual investments in electric energy-efficiency programs of approximately $100 million per year from 2022 through 2025. Pursuant to the IETL, the planned annual investments in electric energy-efficiency programs will increase to approximately $120 million. Ameren Illinois expects to file a revised energy-efficiency plan with the ICC by early March 2022 to reflect the expected increased level of annual investments. 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. In December 2021, 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. This order reflected an increase to the annual performance-based formula rate based on 2020 actual recoverable costs and expected net plant additions for 2021, an increase to include the 2020 revenue requirement reconciliation adjustment including a capital structure composed of 51% common equity, and an increase for the conclusion of the 2019 revenue requirement reconciliation adjustment, which was fully refunded to customers in 2021, consistent with the ICC’s December 2020 annual update filing order. In December 2021, the ICC issued an order in Ameren Illinois’ annual update filing that approved electric customer energy-efficiency rates of $61 million beginning in January 2022, which represents an increase of $10 million from 2021 rates. In February 2021, Ameren’s board of directors increased the quarterly common stock dividend to 55 cents per share, resulting in an annualized equivalent dividend rate of $2.20 per share. In February 2022, Ameren’s board of directors increased the quarterly common stock dividend to 59 cents per share, resulting in an annualized equivalent dividend rate of $2.36 per share. 40 Earnings Net income attributable to Ameren common shareholders was $990 million, or $3.84 per diluted share, for 2021, and $871 million, or $3.50 per diluted share, for 2020. Net income was favorably affected in 2021, compared with 2020, by increased infrastructure investments across all business segments; increased Ameren Missouri electric retail sales, primarily resulting from improving economic conditions and the effects of weather; and by the results of Ameren Missouri’s March 2020 electric rate order. Earnings in 2021, compared with 2020, were also favorably affected by higher delivery service rates at Ameren Illinois Natural Gas and a higher recognized ROE at Ameren Illinois Electric Distribution. Net income was unfavorably affected in 2021, compared with 2020, by the effect of dilution and higher other operations and maintenance expenses at Ameren Missouri due to the amortization of expenses related to the 2020 scheduled refueling and maintenance outage at the Callaway Energy Center and increased non-nuclear energy center and distribution maintenance costs, as well as higher other operations and maintenance expenses due to increased infrastructure maintenance and compliance costs at Ameren Illinois Natural Gas. Earnings in 2021, compared with 2020, were also unfavorably affected by the absence in 2021 of the FERC’s May 2020 order addressing the allowed base ROE for FERC regulated transmission rate base under the MISO tariff, which increased earnings in the year-ago period, and the result of the FERC’s March 2021 order, primarily related to the historical recovery of materials and supplies inventories; increased financing costs at Ameren (parent) and Ameren Missouri, primarily due to higher long-term debt balances; and increased depreciation and amortization expenses not recoverable under riders or trackers at Ameren Missouri and Ameren Illinois Natural Gas, primarily due to additional property, plant, and equipment investments. Liquidity At December 31, 2021, Ameren, on a consolidated basis, had available liquidity in the form of cash on hand and amounts available under the Credit Agreements of $1.8 billion. 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. During 2021, Ameren issued 1.8 million shares of common stock and received proceeds of $148 million. In September 2021, December 2021, and January 2022, Ameren entered into forward sale agreements under the ATM program with counterparties relating to 0.4 million, 0.5 million, and 0.2 million shares of common stock, respectively. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for additional information. 41 Ameren remains focused on strategic capital allocation. The following chart presents 2021 capital expenditures by segment and the midpoint of projected cumulative capital expenditures for 2022 through 2026 by segment: 2021 Capital Expenditures by Segment (Total Ameren – $3.5 billion) (in billions) Midpoint of 2022 – 2026 Projected Capital Expenditures by Segment (Total Ameren – $17.3 billion) (in billions) $0.6 $0.3 $0.6 $3.5 $2.0 $1.8 $8.9 $3.1 Ameren Missouri(a) Ameren Illinois Natural Gas Ameren Illinois Electric Distribution Ameren Transmission (a) Ameren Missouri’s capital expenditures include $525 million for wind generation expenditures for the year ended December 31, 2021. Ameren Missouri’s projected capital expenditures for 2022 through 2026 includes approximately $0.7 billion of capital expenditures related to coal-fired generation. For 2022 through 2026, Ameren’s cumulative capital expenditures are projected to range from $16.6 billion to $18.0 billion. The following table presents the range of projected spending by segment: Ameren Missouri(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Electric Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Range (in billions) $ 8.5 – 3.0 – 1.7 – 3.4 – $ 16.6 – $ 9.2 3.3 1.8 3.7 $ 18.0 (a) Amounts exclude renewable generation investment opportunities of 1,200 MWs by 2026, which are included in Ameren Missouri’s 2020 IRP, and additional 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. RESULTS OF OPERATIONS Our results of operations and financial position are affected by many factors. Economic conditions, including those resulting from the COVID-19 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, and our pension and postretirement benefits costs. Almost all of our 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 II, Item 8, of this report for additional information regarding Ameren Missouri’s, Ameren Illinois’, and ATXI’s regulatory frameworks. 42 We continue to assess the impacts of the COVID-19 pandemic on our businesses, including impacts on electric and natural gas sales volumes, 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. Our accounts receivable balances that were past due or that were a part of a deferred payment arrangement are more comparable to pre-pandemic levels. As of December 31, 2021, accounts receivable balances that were 30 days or greater past due or that were a part of a deferred payment arrangement represented 20%, 17%, and 24%, or $94 million, $34 million, and $60 million, of Ameren’s, Ameren Missouri’s, and Ameren Illinois’ customer trade receivables before allowance for doubtful accounts, respectively. As of December 31, 2019, these percentages were 18%, 18%, and 20%, or $75 million, $30 million, and $45 million, for Ameren, Ameren Missouri, and Ameren Illinois, respectively. Ameren Missouri’s electric sales volumes have been, and continue to be, affected by the COVID-19 pandemic, including a shift in sales volumes by customer class compared to pre-pandemic levels, with an increase in residential sales, and a decrease in commercial and industrial sales, excluding the estimated effects of weather and customer energy-efficiency programs. 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, inflation, and many other factors. We have natural gas cost recovery mechanisms for our Illinois and Missouri natural gas distribution businesses, a purchased power cost recovery mechanism for Ameren Illinois’ electric distribution business, and a FAC for Ameren Missouri’s electric business. We employ various risk management strategies to reduce our exposure to commodity risk and other risks inherent in our business. The reliability of Ameren Missouri’s energy centers and our transmission and distribution systems and the level and timing of operations and maintenance costs and capital investment are key factors that we seek to manage in order to optimize our results of operations, financial position, and liquidity. Earnings Summary The following table presents a summary of Ameren’s earnings for the years ended December 31, 2021 and 2020: Net income attributable to Ameren common shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Earnings per common share – diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 990 3.84 871 3.50 2021 2020 Net income attributable to Ameren common shareholders in 2021 increased $119 million, or $0.34 per diluted share, from 2020. The increase was due to net income increases of $82 million, $22 million, $14 million, and $9 million at Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Transmission, and Ameren Illinois Natural Gas, respectively. The increases in net income were partially offset by an increase in the net loss for activity not reported as part of a segment, primarily at Ameren (parent) of $8 million. Earnings per share in 2021, compared with 2020, were favorably affected by: • • • • • • • • investments in infrastructure and wind generation pursuant to the PISA and the RESRAM, which resulted in increased deferral of interest expense (21 cents per share); increased rate base investments at Ameren Transmission and Ameren Illinois Electric Distribution and a higher recognized ROE at Ameren Illinois Electric Distribution, which increased revenues at these segments (19 cents per share); the results of the MoPSC’s March 2020 electric rate order, which reduced the base level of expenses at Ameren Missouri, partially offset by lower base rates, net of recovery for amounts associated with the reduction in sales volumes resulting from MEEIA programs and recoverable depreciation under the PISA (10 cents per share); increased electric retail sales, excluding the estimated effects of weather and MEEIA, at Ameren Missouri, largely due to improving economic conditions, which resulted in increased sales volumes (10 cents per share); higher base rates pursuant to the ICC's January 2021 natural gas rate order, which increased margins at Ameren Illinois Natural Gas (8 cents per share); higher other income, net, due to the absence of charitable donations made in 2020 pursuant to the MoPSC’s March 2020 electric rate order, increased earnings from equity method investments to advance clean and resilient energy technologies, and a return to more normal levels of charitable donations at Ameren (parent) (8 cents per share); the impact of weather on electric retail sales at Ameren Missouri, primarily resulting from warmer summer temperatures experienced in 2021 (estimated at 6 cents per share); and the results of true-ups to the 2020 revenue requirement reconciliation adjustment in 2021 related to Ameren Illinois’ rates for electric distribution delivery service and electric customer energy-efficiency program investments (2 cents per share). 43 Earnings per share in 2021, compared with 2020, were unfavorably affected by: • • • • • • increased other operations and maintenance expenses at Ameren Missouri, primarily due to the amortization of expenses related to the 2020 scheduled refueling and maintenance outage at the Callaway Energy Center and increased non-nuclear energy center and distribution maintenance costs, and at Ameren Illinois Natural Gas due to increased infrastructure maintenance and compliance activity (17 cents per share); the effect of dilution, primarily due to increased weighted-average basic common shares outstanding resulting from issuances of common shares as detailed in Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report (14 cents per share); the absence in 2021 of the FERC’s May 2020 order addressing the allowed base ROE for FERC regulated transmission rate base under the MISO tariff, which increased Ameren Transmission earnings in the year-ago period, and the result of the FERC’s March 2021 order, primarily related to the historical recovery of materials and supplies inventories, which decreased Ameren Transmission earnings in 2021 (7 cents per share); increased financing costs, primarily at Ameren (parent) and Ameren Missouri, largely due to higher long-term debt balances (5 cents per share); increased depreciation and amortization expenses not recoverable under riders or trackers at Ameren Missouri and Ameren Illinois Natural Gas, primarily due to additional property, plant, and equipment investments (5 cents per share); and decreased income tax benefits at Ameren (parent), primarily related to employee retention tax credits, changes in the distribution of taxable income by state, and company owned life insurance, partially offset by increased amortization of excess deferred income taxes at Ameren Missouri (3 cents per share). The cents per share information presented is based on the weighted-average basic shares outstanding in 2020 and does not reflect any change in earnings per share resulting from dilution, unless otherwise noted. Amounts other than variances related to income taxes have been presented net of income taxes using Ameren’s 2021 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, Taxes Other Than Income Taxes, Other Income, Net, Interest Charges, and Income Taxes, see the major headings below. 44 Below is Ameren’s table of income statement components by segment for the years ended December 31, 2021 and 2020: 2021 Ameren Missouri Electric revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Fuel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas purchased for resale . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance expenses . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (taxes) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncontrolling interests – preferred stock dividends . . . . . . . . . . . . . Net income (loss) attributable to Ameren common shareholders . . . . $ 2020 Electric revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Fuel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas purchased for resale . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance expenses . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (taxes) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncontrolling interests – preferred stock dividends . . . . . . . . . . . . . Net income (loss) attributable to Ameren common shareholders . . . . $ Ameren Illinois Electric Distribution $ 1,639 — (466) 1,173 Ameren Illinois Natural Gas $ — — — — Ameren Transmission 562 $ — — 562 Other / Intersegment Eliminations $ (116) $ — 87 (29) — — — (534) (309) (76) 254 39 (74) (53) 166 (1) 957 (382) 575 (236) (90) (73) 176 13 (42) (39) 108 — — — — (62) (111) (8) 381 15 (83) (82) 231 (1) (1) — (1) 6 (4) (12) (40) 36 (47) 20 (31) — 3,212 (581) (227) 2,404 141 (60) 81 (948) (632) (343) 562 99 (137) (3) 521 (3) 518 $ 165 $ 108 $ 230 $ (31) $ Ameren 5,297 (581) (606) 4,110 1,097 (442) 655 (1,774) (1,146) (512) 1,333 202 (383) (157) 995 (5) 990 $ 523 $ (94) $ 4,911 2,984 $ 1,498 $ (490) (171) 2,323 125 (43) 82 (886) (604) (328) 587 76 (190) (34) 439 (3) — (407) 1,091 — — — (506) (288) (72) 225 33 (72) (42) 144 (1) — — — — 760 (229) 531 (221) (81) (65) 164 13 (41) (36) 100 (1) — — 523 — — — (57) (98) (8) 360 13 (78) (78) 217 (1) — 65 (29) (2) — (2) 9 (4) (10) (36) 16 (38) 35 (23) — (490) (513) 3,908 883 (272) 611 (1,661) (1,075) (483) 1,300 151 (419) (155) 877 (6) 871 436 $ 143 $ 99 $ 216 $ (23) $ 45 Below is Ameren Illinois’ table of income statement components by segment for the years ended December 31, 2021 and 2020: 2021 Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Electric revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Purchased power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,639 (466) 1,173 Natural gas revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas purchased for resale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance expenses . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Preferred stock dividends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income attributable to common shareholder . . . . . . . . . . . . . . . . . . . . . $ 2020 Electric revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Purchased power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas purchased for resale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance expenses . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Preferred stock dividends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income attributable to common shareholder . . . . . . . . . . . . . . . . . . . . . $ Margins — — — (534) (309) (76) 254 39 (74) (53) 166 (1) 165 $ $ 1,498 (407) 1,091 — — — (506) (288) (72) 225 33 (72) (42) 144 (1) 143 $ — — — 957 (382) 575 (236) (90) (73) 176 13 (42) (39) 108 — 108 — — — 760 (229) 531 (221) (81) (65) 164 13 (41) (36) 100 (1) 99 Ameren Illinois Transmission $ 365 — Other / Intersegment Eliminations $ Ameren Illinois 1,938 (400) (66) $ 66 365 — — — (50) (73) (4) 238 14 (48) (51) 153 (1) 152 $ — — — — — — — — — — — — — — $ 329 — 329 — — — (48) (65) (3) 213 13 (42) (46) 138 (1) 137 $ (52) $ 52 — — — — — — — — — — — — — — $ $ 1,538 957 (382) 575 (820) (472) (153) 668 66 (164) (143) 427 (2) 425 1,775 (355) 1,420 760 (229) 531 (775) (434) (140) 602 59 (155) (124) 382 (3) 379 $ $ $ 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 as a complement to the financial information we provide in accordance with GAAP. However, these margins may not be a presentation defined under GAAP, and they may not be comparable to other companies’ presentations or more useful than the GAAP information we provide elsewhere in this report. 46 Electric Margins ) s n o i l l i M ( $ $4,500 $4,000 $3,500 $3,000 $2,500 $2,000 $1,500 $1,000 $500 $0 Total by Segment(a) $4,110 $562 $1,173 $3,908 $523 $1,091 $2,404 $2,323 2021 2020 ) s n o i l l i M ( $ $100 $80 $60 $40 $20 $0 Increase by Segment Overall Ameren Increase of $202 Million $81 $82 $39 $— (a) Includes other/intersegment eliminations of $(29) million and $(29) million in 2021 and 2020, respectively. Ameren Missouri Ameren Illinois Electric Distribution Ameren Transmission Other/Intersegment Eliminations Natural Gas Margins Total by Segment(a) $655 $575 $611 $531 $81 2021 $82 2020 ) s n o i l l i M ( $ $700 $600 $500 $400 $300 $200 $100 $0 ) s n o i l l i M ( $ $50 $45 $40 $35 $30 $25 $20 $15 $10 $5 $0 $(5) Increase (Decrease) by Segment Overall Ameren Increase of $44 Million $44 $1 $(1) (a) Includes other/intersegment eliminations of $(1) million and $(2) million in 2021 and 2020, respectively. Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations 47 The following table presents the favorable (unfavorable) variations by segment for electric and natural gas margins in 2021, compared with 2020: Electric revenue change: 2021 versus 2020 Electric and Natural Gas Margins Ameren Illinois Electric Distribution Ameren Missouri Ameren Illinois Natural Gas Ameren Transmission(a) Other / Intersegment Eliminations Ameren Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Base rates (estimate)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 $ (6) Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MEEIA performance incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system sales, capacity, and FAC revenues, net . . . . . . . . . . . . . . . . . . . . . . . Customer energy-efficiency program investments . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost recovery mechanisms – offset in fuel and purchased power(d) . . . . . . . . . . . . Other cost recovery mechanisms(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenue change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Fuel and purchased power change: Energy costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Sales volumes (excluding the estimated effects of weather) . . . . . . . . . . . . . . . . . Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effect of lower net energy costs included in base rates . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost recovery mechanisms – offset in electric revenue(d) . . . . . . . . . . . . . . . . . . . Total fuel and purchased power change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Net change in electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas revenue change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Base rates (estimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in rate design . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . QIP rider . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost recovery mechanisms – offset in natural gas purchased for resale(d) . . . . . . . . Other cost recovery mechanisms(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total natural gas revenue change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas purchased for resale change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Cost recovery mechanisms – offset in natural gas revenue(d) . . . . . . . . . . . . . . . . . Total natural gas purchased for resale change . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Net change in natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ — 63 — — — 12 6 59 1 — — — — — — — — — — $ $ — 39 — — — — — — — $ — — — — — — — (22) — 24 96 35 3 96 12 12 107 1 $ 39 $ (22) $ 386 35 3 96 — 6 70 — 228 $ 141 $ (99) $ — $ — $ — $ (3) (4) 36 (7) (70) (147) $ 81 $ (4) $ — — — (1) 21 — 16 $ 4 $ (21) (17) $ (1) $ — — — (59) (59) $ 82 $ — — — — — — — — — — — — $ $ $ $ $ $ $ $ — — — — — — — 28 (2) 9 — 153 9 197 $ — $ (153) (153) $ 44 $ — — — — — 39 — — — — — — — — — — — — $ $ $ $ $ $ $ — — — — — 22 22 — — — — — 1 — — 1 — — — 1 $ (99) (3) (4) 36 (7) (107) (184) 202 (4) 28 (2) 9 — 174 9 214 4 (174) (170) 44 $ $ $ $ $ $ $ (c) (a) (b) Includes an increase in transmission electric margins of $36 million in 2021, compared with 2020, at Ameren Illinois. Represents the estimated variation resulting primarily from changes in cooling and heating degree days on electric and natural gas demand compared with the prior year; this variation is based on temperature readings from the National Oceanic and Atmospheric Administration weather stations at local airports in our service territories. For Ameren Illinois Electric Distribution and Ameren Transmission, base rates include increases or decreases to operating revenues related to the revenue requirement reconciliation adjustment under formula rates. For Ameren Missouri, base rates exclude an increase of $7 million for the recovery of lost electric margins in 2021, compared with 2020, resulting from the MEEIA customer energy-efficiency programs. This amount is included in the “sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)” line item. Electric and natural gas revenue changes are offset by corresponding changes in “Fuel,” “Purchased power,” and “Natural gas purchased for resale” on the statement of income, resulting in no change to electric and natural gas margins. Activity in Other/Intersegment Eliminations represents the elimination of related-party transactions between Ameren Missouri, Ameren Illinois, and ATXI, as well as Ameren Transmission revenue from transmission services provided to Ameren Illinois Electric Distribution. See Note 13 – Related-party Transactions and Note 16 – Segment Information under Part II, Item 8, of this report for additional information on intersegment eliminations. (e) Offsetting expense increases or decreases are reflected in “Other operations and maintenance,” “Depreciation and amortization,” or in “Taxes other than income taxes” (d) within the “Operating Expenses” section of the statement of income. These items have no overall impact on earnings. 48 Ameren Ameren’s electric margins increased $202 million, or 5%, in 2021, compared with 2020, because of increased margins at Ameren Missouri, Ameren Illinois Electric Distribution, and Ameren Transmission, as discussed below. Ameren’s natural gas margins increased $44 million, or 7%, between years primarily because of increased margins at Ameren Illinois Natural Gas, as discussed below. Ameren Transmission Ameren Transmission’s electric margins increased $39 million, or 7%, in 2021, compared with 2020. Base rate revenues were favorably affected by continued capital investment (+$23 million), as evidenced by a 12% increase in rate base used to calculate the revenue requirement, and higher recoverable expenses (+$33 million). These increases were partially offset by the absence in 2021 of the FERC’s May 2020 order addressing the allowed base ROE and the effect of the FERC’s March 2021 order (-$17 million), which required refunds primarily related to historical recovery of materials and supplies inventories. See Transmission Formula Rate Revisions in Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information regarding the May 2020 and March 2021 FERC orders. Ameren Missouri Ameren Missouri’s electric margins increased $81 million, or 3%, in 2021, compared with 2020. Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” increased $70 million in 2021, compared with 2020. The increased revenues are fully offset by an increase in fuel and purchased power costs, which increased primarily due to higher electric prices, the absence of the Callaway Energy Center generation and a significant increase in customer demand for electricity in mid-February 2021 due to extremely cold weather. The changes to “Cost recovery mechanisms – offset in fuel and purchased power” are fully offset by “Cost recovery mechanisms – offset in electric revenue” in the table above, and result in no impact to margins. Ameren Missouri’s 5% exposure to net energy costs variances under the FAC is reflected within “Off-system sales, capacity and FAC revenues, net” and “Energy costs”. The following items had a favorable effect on Ameren Missouri’s electric margins in 2021, compared with 2020: • • • Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric sales margins increased an estimated $32 million. The increase was primarily due to an increase in retail sales volumes in 2021, which were unfavorably affected by the COVID-19 pandemic in 2020, partially offset by a decrease in the average retail price per kilowatthour due to changes in customer usage patterns. The change in sales margins is the sum of the change in “Sales volumes and changes in customer usage patterns (excluding the estimated effects of weather and MEEIA)” on electric revenues (+$35 million) and “Sales volumes (excluding the estimated effects of weather)” on fuel and purchased power (-$3 million). While the MEEIA customer energy-efficiency programs reduced retail sales volumes, the recovery of lost electric margins under the MEEIA ensured that electric margins were not affected. The March 2020 MoPSC electric rate order that resulted in lower net energy costs included in base rates, partially offset by lower electric base rates, increased margins $30 million. The change in electric base rates is the sum of the change in “Base rates (estimate)” (-$6 million) and the “Effect of lower net energy costs included in base rates” (+$36 million) in the table above. Summer temperatures were warmer as cooling degree days increased 12%, and winter temperatures were warmer as heating degree days decreased 4%. The aggregate effect of weather increased margins by an estimated $20 million. The change in margins due to weather is the sum of the “Effect of weather (estimate)” on electric revenues (+$24 million) and the “Effect of weather (estimate)” on fuel and purchased power (-$4 million) in the table above. Ameren Missouri’s electric margins decreased $3 million due to higher net energy costs. The absence of the Callaway Energy Center generation and the extremely cold weather in mid-February 2021, partially offset by insurance recoveries related to the unplanned Callaway Energy Center maintenance outage, drove net energy costs higher than those reflected in base rates, resulting from Ameren Missouri’s 5% exposure to net energy cost variances under the FAC. The change in net energy costs is the sum of “Off-system sales, capacity and FAC revenues, net” (+$96 million) and “Energy costs” (-$99 million) in the table above. Ameren Missouri’s natural gas margins were comparable between years. Purchased gas costs increased $21 million in 2021, compared with 2020, primarily resulting from higher natural gas prices throughout 2021 and the significant increase in customer demand and prices for natural gas in mid-February 2021 due to extremely cold weather. The increased purchased gas costs are fully offset by an increase in natural gas revenues under the PGA, resulting in no impact to margin. The increase in purchased gas cost is reflected in “Cost recovery mechanisms – offset in natural gas revenue” and the associated recoveries 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 $118 million, or 8%, in 2021, compared with 2020, driven by increased margins at Ameren Illinois Electric Distribution and Ameren Illinois Transmission. Ameren Illinois Natural Gas’ margins increased $44 million, or 8%, between years. 49 Ameren Illinois Electric Distribution Ameren Illinois Electric Distribution’s margins increased $82 million, or 8%, in 2021, compared with 2020. Purchased power costs increased $59 million in 2021, compared with 2020, primarily resulting from higher electric prices and the significant increase in customer demand for electricity in mid-February 2021 due to extremely cold weather. 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 recoveries 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 Distribution’s margins in 2021, compared with 2020: • • Base rates increased due to a higher recognized ROE (+$9 million), as evidenced by an increase of 49 basis points in the annual average of the monthly yields of the 30-year United States Treasury bonds, increased capital investment (+$10 million), as evidenced by a 8% increase in year-end rate base, higher recoverable non-purchased power expenses (+$35 million), and revenue requirement reconciliation adjustment true-ups for 2020 (+$9 million). The sum of these changes collectively increased margins $63 million. Revenues increased $12 million due to the recovery of and return on increased customer energy-efficiency program investments under performance-based formula ratemaking. Ameren Illinois Natural Gas Ameren Illinois Natural Gas’ margins increased $44 million, or 8%, in 2021, compared with 2020. Purchased gas costs increased $153 million in 2021, compared with 2020, primarily resulting from higher natural gas prices throughout 2021 and the significant increase in customer demand for natural gas in mid-February 2021 due to extremely cold weather. The increased purchased gas costs are fully offset by an increase in natural gas revenues under the PGA, resulting in no impact to margin. The increase in purchased gas cost is reflected in “Cost recovery mechanisms – offset in natural gas revenue” and the associated recoveries 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 in 2021, compared with 2020: • • • Revenues increased $28 million due to higher natural gas base rates as a result of the January 2021 natural gas rate order. Revenues increased $9 million due to additional investment in qualified natural gas infrastructure under the QIP. Other cost recovery mechanisms increased revenues $9 million, primarily due to increased revenues for excise taxes. Ameren Illinois Transmission Ameren Illinois Transmission’s electric margins increased $36 million, or 11%, in 2021, compared with 2020. Margins were favorably affected by increased capital investment (+$23 million), as evidenced by an 18% increase in rate base used to calculate the revenue requirement, and higher recoverable expenses (+$26 million). These increases were partially offset by the absence in 2021 of the FERC’s May 2020 order addressing the allowed base ROE and the effect of the FERC’s March 2021 order (-$13 million), which required refunds primarily related to historical recovery of materials and supplies inventories. See Transmission Formula Rate Revisions in Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information regarding the May 2020 and March 2021 FERC orders. 50 Other Operations and Maintenance Expenses $2,000 $1,500 ) s n o i l l i M ( $ $1,000 $500 $0 Total by Segment(a) $1,774 $236 $534 $1,661 $221 $506 $948 $886 2021 2020 Increase by Segment Overall Ameren Increase of $113 Million $64 $62 ) s n o i l l i M ( $ $48 $32 $16 $0 $28 $15 $5 $3 (a) Includes $62 million and $57 million at Ameren Transmission in 2021 and 2020, respectively, and other/intersegment eliminations of $(6) million and $(9) million in 2021 and 2020, respectively. Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission Ameren Other operations and maintenance expenses at Ameren increased $113 million in 2021, compared with 2020. In addition to changes by segments discussed below, other operations and maintenance expenses increased $3 million in 2021 for activity not reported as part of a segment, as reflected in “Other/Intersegment Eliminations” above, primarily because of increased costs for support services. Ameren Transmission Other operations and maintenance expenses at Ameren Transmission increased $5 million in 2021, compared with 2020, primarily because of increased maintenance activity. Ameren Missouri The $62 million increase in Ameren Missouri’s other operations and maintenance expenses in 2021, compared with 2020, was primarily due to the following items: • • • • • • Energy center maintenance costs, other than Callaway refueling and maintenance costs, increased $29 million, primarily because of costs related to new wind generation facilities, which are recovered under the RESRAM, and the deferral of projects in 2020. Callaway Energy Center refueling and maintenance costs increased $28 million because of the amortization of those costs, beginning in January 2021, which were previously deferred as a regulatory asset, pursuant to the MoPSC’s February 2020 order. Recoverable customer energy-efficiency program costs increased $16 million because of increased participation in the MEEIA programs in 2021. Technology-related expenditures increased $11 million, primarily because of cloud computing licensing costs and software maintenance. Transmission and distribution expenditures increased $6 million, primarily because of increased storm costs. The cash surrender value of company-owned life insurance decreased $6 million because of less favorable market returns in 2021, compared with 2020. 51 The following items partially offset the above increases in other operations and maintenance expenses between years: • • • • Labor and benefit costs decreased $12 million, primarily because of higher capitalization of costs resulting from increased construction activity. Amortization of regulatory balances, primarily solar rebate costs pursuant to the MoPSC’s March 2020 electric rate order and RESRAM deferrals, decreased $11 million. Expenses decreased $10 million because of increased bad debt costs in 2020 largely due to the COVID-19 pandemic. Deferral to a regulatory asset of $5 million of certain costs incurred in 2020 related to the COVID-19 pandemic, pursuant to the MoPSC’s March 2021 orders. Ameren Illinois Other operations and maintenance expenses increased $45 million at Ameren Illinois in 2021, compared with 2020, as discussed below. Other operations and maintenance expenses were comparable at Ameren Illinois Transmission between 2021 and 2020. Ameren Illinois Electric Distribution The $28 million increase in Ameren Illinois Electric Distribution’s other operations and maintenance expenses in 2021, compared with 2020, was primarily due to the following items: • • • • • Amortization of regulatory assets associated with customer energy-efficiency program investments under formula ratemaking increased $8 million. Technology-related expenditures increased $8 million, primarily because of cloud computing licensing costs and software maintenance. Increased bad debt expense of $7 million, primarily because of increased recovery of bad debt costs allowed by the ICC. Expenses increased $5 million because of the true-up of vegetation management expenditures consistent with the December 2021 ICC electric distribution service rate order. The cash surrender value of company-owned life insurance decreased $3 million because of less favorable market returns in 2021 compared with 2020. The above increases were partially offset by a $7 million reduction in environmental remediation rider costs, which resulted from a decline in the required remediation efforts. Ameren Illinois Natural Gas Other operations and maintenance expenses at Ameren Illinois Natural Gas increased $15 million in 2021, compared with 2020, largely due to an $8 million increase in infrastructure maintenance and compliance activity. Other operations and maintenance expenses also increased $5 million because of the absence in 2021 of miscellaneous amortizations of regulatory liabilities, which lowered expenses in 2020. These increases were partially offset by $3 million reduction in recoverable bad debt expense and environmental remediation rider costs consistent with the amounts allowed by the ICC. 52 Depreciation and Amortization Total by Segment(a) $1,200 $1,146 $111 $90 $309 $1,075 $98 $81 $288 $632 $604 ) s n o i l l i M ( $ $1,000 $800 $600 $400 $200 $0 Increase by Segment Overall Ameren Increase of $71 Million $30 $28 $21 ) s n o i l l i M ( $ $20 $10 $0 $13 $9 $— (a) Includes other/intersegment eliminations of $4 million and $4 million in 2021 and 2020, respectively. 2021 2020 Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission The $71 million, $28 million, and $38 million increase in depreciation and amortization expenses in 2021, compared with 2020, at Ameren, Ameren Missouri, and Ameren Illinois, respectively, was primarily due to additional property, plant, and equipment across their respective segments. Ameren’s and Ameren Missouri’s depreciation and amortization expenses reflected a deferral to a regulatory asset of depreciation and amortization expenses pursuant to the PISA and the RESRAM. The PISA and RESRAM deferrals of depreciation and amortization expenses was $98 million and $27 million in 2021 and 2020, respectively. 53 Taxes Other Than Income Taxes Total by Segment(a) Increase by Segment Overall Ameren Increase of $29 Million $512 $73 $76 $343 $483 $65 $72 $328 ) s n o i l l i M ( $ $550 $440 $330 $220 $110 $0 $16 $15 ) s n o i l l i M ( $ $12 $8 $4 $0 $8 $4 $2 $— 2021 2020 (a) Includes $8 million and $8 million at Ameren Transmission in 2021 and 2020, respectively, and other/intersegment eliminations of $12 million and $10 million in 2021 and 2020, respectively. Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission Taxes other than income taxes increased $29 million at Ameren in 2021, compared with 2020, primarily because of increased excise taxes of $11 million and $7 million at Ameren Missouri and Ameren Illinois Natural Gas, respectively, resulting from increased sales. Additionally, taxes other than income taxes increased $5 million, compared with the year-ago period, at Ameren Missouri because of increased property taxes, primarily resulting from the addition of wind generation properties and higher assessed values, partially offset by lower natural gas property taxes. Taxes other than income taxes also increased $3 million at Ameren Illinois Electric Distribution because of increased excise taxes, resulting from decreased tax credits compared with 2020. See Excise Taxes in Note 15 – Supplemental Information under Part II, Item 8, of this report for additional information. 54 Other Income, Net Total by Segment Increase by Segment Overall Ameren Increase of $51 Million $202 $36 $15 $13 $39 $99 $151 $16 $13 $13 $33 $76 ) s n o i l l i M ( $ $210 $180 $150 $120 $90 $60 $30 $0 ) s n o i l l i M ( $ $25 $20 $15 $10 $5 $0 $23 $20 $6 $2 $— 2021 2020 Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission Other income, net, increased $51 million at Ameren in 2021, compared with 2020, primarily because of the following items: • • • • The non-service cost component of net periodic benefit income increased $20 million, primarily because of increases of $9 million, $5 million, and $4 million for Ameren Missouri, Ameren Illinois Electric Distribution, and activity not reported as part of a segment, respectively. Income from equity method investments to advance clean and resilient energy technologies increased $9 million for activity not reported as part of a segment. Charitable donations were $8 million lower at Ameren Missouri due to the absence of charitable donations made in the year-ago period pursuant to the MoPSC’s March 2020 electric rate order. Charitable donations were $7 million lower for activity not reported as part of a segment due to a return to normal levels at Ameren (parent). The equity portion of allowance for funds used during construction increased $7 million at Ameren Missouri due to higher construction work in progress balances during 2021. See Note 6 – Other Income, Net under Part II, Item 8, of this report for additional information. See Note 10 – Retirement Benefits under Part II, Item 8, of this report for more information on the non-service cost components of net periodic benefit income. 55 Increase (Decrease) by Segment Overall Ameren Decrease of $36 Million $9 $5 $2 $1 Interest Charges Total by Segment $419 $38 $78 $41 $72 $190 $383 $47 $83 $42 $74 $137 $11 $0 $(11) $(22) $(33) $(44) ) s n o i l l i M ( $ ) s n o i l l i M ( $ $450 $360 $270 $180 $90 $0 2021 2020 $(55) $(53) Ameren Missouri Ameren Illinois Natural Gas Other/Intersegment Eliminations Ameren Illinois Electric Distribution Ameren Transmission Interest charges decreased $36 million and $53 million in 2021, compared with 2020, at Ameren and Ameren Missouri, respectively, primarily because of increased deferrals to a regulatory asset of interest charges pursuant to the PISA and RESRAM. The PISA and RESRAM deferrals of interest charges were $82 million and $12 million in 2021 and 2020, respectively. Interest charges increased $9 million at Ameren Illinois in 2021, compared with 2020, as discussed below. The following items partially offset the above decreases in interest charges in 2021, compared with 2020: • • • Issuances of long-term debt at Ameren Missouri in October 2020 and June 2021 collectively increased interest charges by $11 million and $6 million, respectively. Issuance of long-term debt at Ameren (parent) in April 2020 increased interest charges by $7 million. Interest charges at Ameren Illinois Transmission increased by $5 million as a result of the Ameren Illinois issuances of long-term debt in November 2020 and June 2021 and a March 2021 FERC order, primarily related to the historical recovery of materials and supplies inventories. 56 Income Taxes The following table presents effective income tax rates for the years ended December 31, 2021 and 2020: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Electric Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2021 14% 1% 25% 24% 27% 25% 26% 2020 15% 7% 24% 22% 26% 25% 26% See Note 12 – Income Taxes under Part II, Item 8, of this report for information regarding reconciliations of effective income tax rates for Ameren, Ameren Missouri, and Ameren Illinois. The effective income tax rate was higher at Ameren Illinois Electric Distribution in 2021, compared with 2020, primarily because of decreased tax benefits from certain depreciation differences on property-related items largely attributable to lower amortization of excess deferred taxes. LIQUIDITY AND CAPITAL RESOURCES Collections from our tariff-based revenues are our principal source of cash provided by operating activities. A diversified retail customer mix, primarily consisting of rate-regulated residential, commercial, and industrial customers, provides us with a reasonably predictable source of cash. In addition to using cash provided by operating activities, we use available cash, drawings under committed credit agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings to support normal operations and temporary capital requirements. We may reduce our short-term borrowings with cash provided by operations or, at our discretion, with long-term borrowings, or, in the case of Ameren Missouri and Ameren Illinois, with capital contributions from Ameren (parent). In addition, to support a portion of its fuel requirements for generation, Ameren Missouri has entered into various long-term commitments to meet these requirements. Ameren Missouri and Ameren Illinois also have entered into various long-term commitments for purchased power and natural gas for distribution. Ameren’s, Ameren Missouri’s, and Ameren Illinois’ estimated minimum purchase obligations associated with these commitments totaled $1.6 billion, $0.7 billion, and, $0.8 billion, respectively, which include $0.7 billion, $0.3 billion, and, $0.4 billion, respectively, in 2022. We expect to make significant capital expenditures over the next five years, as discussed in the Capital Expenditures sections below, 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 this report. As part of its funding plan for capital expenditures, Ameren is using newly issued shares of common stock, rather than market-purchased shares, to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 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. During 2021, Ameren issued a total of 3.4 million shares of common stock and received aggregate proceeds of $261 million under the ATM program and the settlement of the remaining portion of the August 2019 forward sale agreement. Ameren plans to issue approximately $300 million of equity each year from 2022 to 2026 in addition to issuances under the DRPlus and employee benefit plans. Ameren expects its equity to total capitalization to be about 45% through December 31, 2026, with the long-term intent to support solid investment-grade credit ratings. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for additional information on the ATM program, the 2021 settlement of the remaining portion of the August 2019 forward sale agreement, and the September 2021, December 2021, and January 2022 forward sale agreements. 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 December 31, 2021, for Ameren, Ameren Missouri, and Ameren Illinois. With the credit capacity available under the Credit Agreements, and cash and cash equivalents, Ameren (parent), Ameren Missouri, and Ameren Illinois, collectively had net available liquidity of $1.8 billion at December 31, 2021. See Credit Facility Borrowings and Liquidity and Long-term Debt and Equity below for additional information. 57 The following table presents net cash provided by (used in) operating, investing, and financing activities for the years ended December 31, 2021 and 2020: Net Cash Provided By Operating Activities 2020 Variance 2021 Net Cash Used In Investing Activities 2020 Variance 2021 Net Cash Provided By Financing Activities 2020 Variance 2021 Ameren . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . 1,661 $ 1,727 $ (66) $ (3,528) $ (3,329) $ (199) $ 1,721 $ 1,727 $ 929 662 911 679 18 (17) (1,922) (1,437) (1,904) (1,444) (18) 7 856 761 1,099 787 (6) (243) (26) Cash Flows from Operating Activities Our cash provided by operating activities is affected by fluctuations of trade accounts receivable, inventories, and accounts and wages payable, among other things, as well as the unique regulatory environment for each of our businesses. Substantially all expenditures related to fuel, purchased power, and natural gas purchased for resale are recovered from customers through rate adjustment mechanisms, which may be adjusted without a traditional regulatory rate review, subject to prudence reviews. Similar regulatory mechanisms exist for certain other operating expenses that can also affect the timing of cash provided by operating activities. The timing of cash payments for costs recoverable under our regulatory mechanisms differs from the recovery period of those costs. Additionally, the seasonality of our electric and natural gas businesses, primarily caused by seasonal customer rates and changes in customer demand due to weather, such as increased demand resulting from the extremely cold weather in mid-February 2021, significantly affects the amount and timing of our cash provided by operating activities. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for more information about our regulatory frameworks. Ameren Ameren’s cash provided by operating activities decreased $66 million in 2021, compared with 2020. The following items contributed to the decrease: • • • • • • • • • • • • • • • • A $62 million increase in payroll tax payments primarily due to the employer portion of Social Security taxes as a result of a payment deferral allowed in 2020 under the Coronavirus Aid, Relief, and Economic Security Act. Half of the 2020 deferral was paid at the end of 2021 and the remaining half will be paid at the end of 2022. A $49 million increase in the cost of natural gas held in storage, primarily at Ameren Illinois, because of higher prices. A $44 million decrease in net collateral activity with counterparties, primarily resulting from changes in the market prices of power, natural gas, and other fuels. A $43 million increase in interest payments, primarily due to an increase in the average outstanding debt. An $18 million increase in energy center maintenance costs, other than those associated with the Callaway refueling and maintenance outage, at Ameren Missouri, primarily because of costs related to new wind generation facilities. A $15 million increase in major storm restoration costs at Ameren Illinois, primarily due to a January 2021 storm. An $8 million increase in pension and postretirement benefit plan contributions. A $6 million increase in payments to contractors at Ameren Illinois, primarily related to distribution expenditures for increased natural gas infrastructure maintenance and compliance costs. A $6 million increase in property tax payments at Ameren Missouri due to higher assessed property tax values. The following items partially offset the decrease in Ameren’s cash from operating activities between periods: A $74 million increase due to the net impact of customer collections, the effect of riders, and increased commodity costs. An increase at Ameren Missouri, as discussed below, and increased customer collections at ATXI were partially offset by a decrease at Ameren Illinois, as discussed below. A $30 million decrease in payments for nuclear refueling and maintenance outages at Ameren Missouri’s Callaway Energy Center. There was no scheduled refueling and maintenance outage in 2021. A $21 million decrease in payments to settle ARO liabilities, primarily related to the closure of Ameren Missouri’s CCR storage facilities. A $21 million increase, primarily resulting from reduced purchases of materials and supplies at Ameren Illinois to support operations in 2021 as levels were increased in 2020 to mitigate against potential supply disruptions associated with the COVID-19 pandemic. A $21 million increase resulting from a reduction in payments for certain cloud computing arrangements. A $14 million increase resulting from income tax refunds of $1 million in 2021, compared with income tax payments of $13 million in 2020, primarily from lower taxable income and the timing of payments in 2021. A $12 million decrease in payments related to charitable donations. 58 Ameren Missouri Ameren Missouri’s cash provided by operating activities increased $18 million in 2021, compared with 2020. The following items contributed to the increase: • • • • • • • • • • An $86 million increase due to the net impact of customer collections, the effect of riders, and increased commodity costs. The increase resulted from increased retail sales and a net increase attributable to riders, excluding the PGA. These increases were partially offset by increased purchases for natural gas for resale and purchased power as a result of the significant increase in customer demand and increased prices for natural gas and electricity experienced in mid-February 2021 due to extremely cold weather, which also contributed to a net decrease under the PGA, and a decrease in collections of outstanding account receivables. See Outlook below for additional information about the extension of the collection period for the PGA related to the extremely cold weather in mid-February 2021. A $30 million decrease in payments for nuclear refueling and maintenance outages at the Callaway Energy Center. There was no scheduled refueling and maintenance outage in 2021. A $22 million decrease in payments to settle ARO liabilities, primarily related to the closure of CCR storage facilities. An $11 million increase resulting from a reduction in payments for certain cloud computing arrangements. The following items partially offset the increase in Ameren Missouri’s cash from operating activities between periods: A $45 million decrease in net collateral activity with counterparties, primarily resulting from changes in the market prices of power, natural gas, and other fuels. A $28 million increase in payroll tax payments primarily due to the employer portion of Social Security taxes as a result of a payment deferral allowed in 2020 under the Coronavirus Aid, Relief, and Economic Security Act. Half of the 2020 deferral was paid at the end of 2021 and the remaining half will be paid at the end of 2022. An $18 million increase in energy center maintenance costs, other than those associated with the Callaway refueling and maintenance outage, primarily because of costs related to new wind generation facilities. A $15 million increase in interest payments, primarily due to an increase in the average outstanding debt. A $6 million increase in property tax payments due to higher assessed property tax values. A $5 million increase in pension and postretirement benefit plan contributions. Ameren Illinois Ameren Illinois’ cash provided by operating activities decreased $17 million in 2021, compared with 2020. The following items contributed to the decrease: • • • • • • • • • A $45 million increase in the cost of natural gas held in storage because of higher prices. A $27 million decrease due to the net impact of commodity costs, the effect of riders, and customer collections. The decrease resulted from increased purchases for natural gas for resale and purchased power as a result of the significant increase in customer demand and increased prices for natural gas and electricity experienced in mid-February 2021 due to extremely cold weather, which also contributed to a net decrease under the PGA, and a net decrease attributable to other riders. The decrease from riders was partially offset by increased retail sales; the effect of the phase-in of collection activities beginning in April 2021, which had been suspended for most of 2020; increased customer collections resulting from base rate increases pursuant to the January 2021 natural gas rate order and due to electric transmission rate base growth; and state funding received for customer billing assistance. See Outlook below for additional information about the extension of the collection period for the PGA related to the extremely cold weather in mid-February 2021. A $21 million increase in payroll tax payments primarily due to the employer portion of Social Security taxes as a result of a payment deferral allowed in 2020 under the Coronavirus Aid, Relief, and Economic Security Act. Half of the 2020 deferral was paid at the end of 2021 and the remaining half will be paid at the end of 2022. A $15 million increase in major storm restoration costs, primarily due to a January 2021 storm. An $11 million increase in interest payments, primarily due to an increase in the average outstanding debt. A $6 million increase in payments to contractors primarily related to distribution expenditures for increased natural gas infrastructure maintenance and compliance costs. The following items partially offset the decrease in Ameren Illinois’ cash from operating activities between periods: An $82 million increase resulting from income tax refunds of $41 million in 2021, compared with income tax payments of $41 million in 2020, from Ameren (parent) pursuant to the tax allocation agreement, primarily from lower taxable income and the timing of payments in 2021. A $21 million increase, primarily resulting from reduced purchases of materials and supplies to support operations in 2021 as levels were increased in 2020 to mitigate against potential supply disruptions associated with the COVID-19 pandemic. A $10 million increase resulting from a reduction in payments for certain cloud computing arrangements. 59 Cash Flows from Investing Activities Ameren’s cash used in investing activities increased $199 million during 2021, compared with 2020, primarily as a result of a $246 million increase in capital expenditures, net of a decrease in wind generation expenditures. Increased capital expenditures at Ameren Missouri were partially offset by decreased expenditures at Ameren Illinois and ATXI. See discussion of changes at Ameren Missouri and Ameren Illinois below. ATXI’s capital expenditures decreased $66 million, primarily as a result of placing the ninth and final line segment of the Illinois Rivers transmission line in service in December 2020. Ameren’s increase in capital expenditures was partially offset by a $28 million decrease in net investment activity in the nuclear decommissioning trust fund at Ameren Missouri and a $22 million decrease due to the timing of nuclear fuel expenditures. Ameren Missouri’s cash used in investing activities increased $18 million during 2021, compared with 2020, primarily as a result of a $349 million increase in capital expenditures, primarily related to electric delivery infrastructure upgrades and electric transmission system reliability projects partially offset by a decrease in wind generation expenditures. The increase in capital expenditures was partially offset by a $278 million decrease related to money pool advances activity, a $28 million decrease in net investment activity in the nuclear decommissioning trust fund, and a $22 million decrease due to the timing of nuclear fuel expenditures. Ameren Illinois’ cash used in investing activities decreased $7 million during 2021, compared with 2020, due to decreased capital expenditures, primarily related to electric transmission system reliability projects and natural gas infrastructure, partially offset by electric delivery infrastructure upgrades. Capital Expenditures The following charts present our capital expenditures for the years ended December 31, 2021 and 2020: 2021 – Total Ameren $3,479(a) 2020 – Total Ameren $3,233(a) $41 $575 $278 $579 $113 $603 $2,015 $301 $1,666 $543 Ameren Missouri(b) Ameren Illinois Natural Gas ATXI and other electric transmission subsidiaries Ameren Illinois Electric Distribution Ameren Illinois Transmission (a) (b) Includes Other capital expenditures of $(9) million and $7 million for the years ended December 31, 2021 and 2020, respectively, which includes amounts for the elimination of intercompany transfers. Ameren Missouri’s capital expenditures include $525 million and $564 million for wind generation expenditures for the years ended December 31, 2021 and 2020, respectively. Ameren’s 2021 capital expenditures consisted of expenditures made by its subsidiaries, including ATXI and other electric transmission subsidiaries, which spent $41 million. Of the $278 million in capital expenditures spent by Ameren Illinois Natural Gas during 2021, $170 million related to natural gas projects eligible for QIP recovery. In addition, Ameren Missouri expenditures included $525 million for wind generation, primarily for the acquisition of the Atchison Renewable Energy Center. In both years, other capital expenditures were made principally to maintain, upgrade, and improve the reliability of the transmission and distribution systems of Ameren Missouri and Ameren Illinois by investing in substation upgrades, energy center projects, and smart-grid technology. Additionally, the Ameren Companies invested 60 in various software projects. As of December 31, 2021, Ameren Illinois exceeded the minimum capital spending levels required pursuant to IEIMA. Ameren’s 2020 capital expenditures consisted of expenditures made by its subsidiaries, including ATXI and other electric transmission subsidiaries, which spent $113 million primarily on the Illinois Rivers transmission line. Of the $301 million in capital expenditures spent by Ameren Illinois Natural Gas during 2020, $189 million related to natural gas projects eligible for QIP recovery. In addition, Ameren Missouri expenditures included $564 million for the acquisition of the High Prairie Renewable Energy Center. The following table presents Ameren’s estimate of capital expenditures that will be incurred from 2022 through 2026, including construction expenditures, allowance for funds used during construction, and expenditures for compliance with existing environmental regulations: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois Electric Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Natural Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATXI and other electric transmission subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2022 2023 – 2026 1,690 $ 580 370 650 85 5 3,380 $ 6,805 – $ 2,405 – 1,320 – 2,580 – 105 – 20 – 13,235 – $ 7,520 2,660 1,455 2,855 115 20 14,625 Total 8,495 – $ 2,985 – 1,690 – 3,230 – 190 – 25 – 16,615 – $ $ $ 9,210 3,240 1,825 3,505 200 25 18,005 Ameren Missouri’s estimated capital expenditures include transmission, distribution, grid modernization, and generation-related investments, as well as expenditures for compliance with environmental regulations. Capital expenditures related to coal-fired generation of approximately $0.7 billion are included in Ameren Missouri’s estimated capital expenditures. Ameren Illinois’ estimated capital expenditures are primarily for electric and natural gas transmission and distribution-related investments, including capital expenditures to modernize its electric and gas distribution systems. These planned investments are based on the assumption of continued constructive regulatory frameworks, including an assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA from December 2023 to December 2028. Ameren’s and Ameren Missouri’s estimated capital expenditures exclude renewable generation investment opportunities of 1,200 MWs by 2026, which are included in Ameren Missouri’s 2020 IRP, and additional 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. In April 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 February 2022, the MISO updated a list of projects under consideration for the first phase of the roadmap, and is expected to approve certain projects for the first phase by mid-2022. Expenditures that result from the MISO long-range transmission planning roadmap may cause adjustments to our estimated 2022 through 2026 capital expenditures. Ameren Missouri continually reviews its generation portfolio and expected power needs. As a result, Ameren Missouri could modify its plan for generation capacity, the type of generation asset technology that will be employed, and whether capacity or power may be purchased, among other changes. Additionally, we continually review the reliability of our transmission and distribution systems, expected capacity needs, and opportunities for transmission investments within and outside our service territories. The timing and amount of investments could vary because of changes in expected capacity, the condition of transmission and distribution systems, and our ability and willingness to pursue transmission investments, as well as our ability to obtain necessary regulatory approvals, among other factors. Any changes in future generation, transmission, or distribution needs could result in significant changes in capital expenditures or losses, which could be material. Compliance with environmental regulations could also have significant impacts on the level of capital expenditures. Environmental Capital Expenditures Ameren Missouri will continue to incur costs to comply with federal and state regulations, including those requiring the reduction of SO2, NOx, and mercury emissions from its coal-fired energy centers. See Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for a discussion of existing and proposed environmental laws that affect, or may affect, our facilities and capital expenditures to comply with such laws. 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. 61 Ameren’s cash provided by consolidated financing activities decreased $6 million during 2021, compared with 2020. During 2021, Ameren utilized net proceeds of $1,997 million from the issuance of long-term debt for general corporate purposes, including 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 discussed above, and to fund, in part, investing activities. In 2021, Ameren received $55 million from net commercial paper issuances. In addition, Ameren received aggregate cash proceeds of $308 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 August 2019 forward sale agreement. These proceeds, along with cash on hand, were used to fund a portion of Ameren Missouri’s wind generation investments and to fund, in part, other investing activities. In comparison, in 2020, Ameren utilized net proceeds of $2,183 million from the issuance of long-term debt for general corporate purposes, including to repay then-outstanding short-term debt, including short-term debt incurred in connection with the repayment at maturity of long-term debt, to partially finance the acquisition of two wind generation facilities, and to repay other long-term debt. In addition, in 2020, Ameren received cash proceeds of $425 million from the partial settlement of a forward sale agreement of common stock that were used to fund a portion of Ameren Missouri’s wind generation investments. Collectively, in 2020, Ameren repaid long-term debt of $442 million, received $50 million from net commercial paper issuances, and used cash provided by financing activities to fund, in part, investing activities. During 2021, Ameren paid common stock dividends of $565 million, compared with $494 million in dividend payments in 2020. Ameren Missouri’s cash provided by financing activities decreased $243 million during 2021, compared with 2020. During 2021, Ameren Missouri utilized net proceeds of $524 million from the issuance of long-term debt 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 discussed above. Additionally, the proceeds from the issuance of long-term debt and $207 million of capital contributions from Ameren (parent) were used to fund, in part, investing activities. In 2021, Ameren Missouri also received $165 million from commercial paper issuances. In comparison, in 2020, Ameren Missouri utilized cash on hand and net proceeds of $1,012 million from the issuance of long-term debt to repay then- outstanding short-term debt, including short-term debt incurred in connection with the repayment of maturity of long-term debt, and to partially finance the acquisition of two wind generation facilities. In 2020, Ameren Missouri also received $491 million in capital contributions from Ameren (parent). Collectively, in 2020, Ameren Missouri repaid long-term debt of $92 million, repaid net short-term debt of $234 million, and used cash provided by financing activities to fund, in part, investing activities. During 2021, Ameren Missouri paid common stock dividends of $24 million, compared with $66 million in dividend payments in 2020. Ameren Illinois’ cash provided by financing activities decreased $26 million during 2021, compared with 2020. During 2021, Ameren Illinois utilized net proceeds of $449 million from the issuance of long-term debt 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 discussed above. Additionally, the proceeds from the issuance of long-term debt and $262 million of capital contributions from Ameren (parent) were used to fund, in part, investing activities. In 2021, Ameren Illinois also received $103 million from commercial paper issuances. In addition, Ameren Illinois repaid $19 million of money pool borrowings and redeemed $13 million of preferred stock in 2021. In comparison, in 2020, Ameren Illinois received $464 million in capital contributions from Ameren (parent). In addition, in 2020, Ameren Illinois utilized net proceeds of $373 million from the issuance of long-term debt to repay then-outstanding short-term debt. Collectively, in 2020 Ameren Illinois repaid net short-term debt of $53 million, borrowed $19 million from the money pool, and used cash provided by financing activities to fund, in part, investing activities. Credit Facility Borrowings and Liquidity The liquidity needs of the Ameren Companies are typically supported through the use of available cash, drawings under committed credit agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for additional information on credit agreements, commercial paper issuances, Ameren’s money pool arrangements and related borrowings, and relevant interest rates. 62 The following table presents Ameren’s consolidated net available liquidity as of December 31, 2021: Available at December 31, 2021 Ameren (parent) and Ameren Missouri(a): Missouri Credit Agreement – borrowing capacity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Ameren (parent) commercial paper outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Ameren Missouri commercial paper outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Less: Letters of credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Missouri Credit Agreement – subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren (parent) and Ameren Illinois(b): Illinois Credit Agreement – borrowing capacity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Ameren (parent) commercial paper outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Ameren Illinois commercial paper outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Illinois Credit Agreement – subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net available liquidity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 1,200 178 165 2 855 1,100 99 103 898 1,753 8 1,761 (a) The maximum aggregate amount available to Ameren (parent) and Ameren Missouri under the Missouri Credit Agreement is $900 million and $850 million, respectively. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for further discussion of the Credit Agreements. (b) The maximum aggregate amount available to Ameren (parent) and Ameren Illinois under the Illinois Credit Agreement is $500 million and $800 million, respectively. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for further discussion of the Credit Agreements. In December 2021, the Credit Agreements, which were scheduled to mature in December 2024, were extended and now mature in December 2025. The Credit Agreements provide $2.3 billion of credit through December 2025. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for additional information on the Credit Agreements. During the year ended December 31, 2021, 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. The issuance of short-term debt securities by Ameren’s utility subsidiaries is subject to FERC approval under the Federal Power Act. In 2020, the FERC issued orders authorizing Ameren Missouri and Ameren Illinois to each issue up to $1 billion of short-term debt securities through March 2022 and September 2022, respectively. In July 2021, the FERC issued an order authorizing ATXI to issue up to $300 million of short-term debt securities through 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 short-term borrowing arrangements, or other arrangements may be made. 63 Long-term Debt and Equity The following table presents Ameren’s issuances (net of any issuance premiums or discounts) of long-term debt and equity, as well as redemptions and maturities of long-term debt and preferred stock for the years ended December 31, 2021 and 2020. For additional information related to the terms and uses of these issuances and effective registration statements, and Ameren’s forward sale agreements relating to common stock, see Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report. For information on capital contributions received by Ameren Missouri and Ameren Illinois from Ameren (parent), see Note 13 – Related-party Transactions under Part II, Item 8, of this report. Month Issued, Redeemed, Repurchased, or Matured 2021 2020 Issuances of Long-term Debt Ameren: 1.75% Senior unsecured notes due 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.95% Senior unsecured notes due 2027 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.50% Senior unsecured notes due 2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: 2.15% First mortgage bonds due 2032 (green bonds) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.95% First mortgage bonds due 2030 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.625% First mortgage bonds due 2051 (green bonds) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: 2.90% First mortgage bonds due 2051 (green bonds) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.375% First mortgage bonds due 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.55% First mortgage bonds due 2030 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATXI:(a) 2.45% Senior unsecured notes due 2036 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren long-term debt issuances Issuances of Common Stock Ameren: DRPlus and 401(k)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2019 forward sale agreement(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATM program(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren common stock issuances(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Maturities of Long-term Debt Ameren: 2.70% Senior unsecured notes due 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: 5.00% Senior secured notes due 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . City of Bowling Green financing obligation (Peno Creek CT) . . . . . . . . . . . . . . . . . . . . . . . . . Total long-term debt redemptions, repurchases, and maturities . . . . . . . . . . . . . . . . . . . . . . . . . . Redemptions of Preferred Stock Ameren Illinois: March November April June March October June June November November Various Various Various October February December 6.625% Series . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.75% Series . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . March March Total Ameren Illinois preferred stock redemptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ $ $ 450 499 — 524 — — 349 100 — 75 1,997 47 113 148 308 — — 8 8 12 1 13 $ $ $ $ $ $ $ $ — — 798 — 465 547 — 373 — 2,183 51 425 — 476 350 85 7 442 — — — (a) Pursuant to a note purchase agreement, ATXI agreed to issue $95 million principal amount of 2.96% senior unsecured notes due 2052, see Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for further information. (b) Ameren issued a total of 0.5 million and 0.7 million shares of common stock under its DRPlus and 401(k) plan in 2021 and 2020, respectively. (c) Ameren issued 1.6 million shares of common stock in February 2021 to settle the remainder of the August 2019 forward sale agreement. Ameren issued 5.9 million shares of common stock pursuant to a partial settlement of the August 2019 forward sale agreement in December 2020. (d) Ameren issued 1.8 million shares of common stock under the ATM program in 2021. (e) Excludes 0.5 million and 0.5 million shares of common stock valued at $33 million and $38 million issued for no cash consideration in connection with stock-based compensation in 2021 and 2020, respectively The Ameren Companies may sell securities registered under their effective registration statements if market conditions and capital requirements warrant such sales. Any offer and sale will be made only by means of a prospectus that meets the requirements of the Securities Act of 1933 and the rules and regulations thereunder. 64 Indebtedness Provisions and Other Covenants At December 31, 2021, the Ameren Companies were in compliance with the provisions and covenants contained within 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 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for a discussion of covenants and provisions (and applicable cross-default provisions) contained in our credit agreements, certain of the Ameren Companies’ indentures and articles of incorporation, and ATXI’s note purchase agreements. 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 Ameren’s, Ameren Missouri’s, 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. Dividends Ameren paid to its shareholders common stock dividends totaling $565 million, or $2.20 per share, in 2021 and $494 million, or $2.00 per share, in 2020. The amount and timing of dividends payable on Ameren’s common stock are within the sole discretion of Ameren’s board of directors. Ameren’s board of directors has not set specific targets or payout parameters when declaring common stock dividends, but it considers various factors, including Ameren’s overall payout ratio, payout ratios of our peers, projected cash flow and potential future cash flow requirements, historical earnings and cash flow, projected earnings, impacts of regulatory orders or legislation, and other key business considerations. Ameren expects its dividend payout ratio to be between 55% and 70% of earnings over the next few years. On February 11, 2022, the board of directors of Ameren declared a quarterly dividend on Ameren’s common stock of 59 cents per share, payable on March 31, 2022, to shareholders of record on March 9, 2022. Certain of our financial agreements and corporate organizational documents contain covenants and conditions that, among other things, restrict the Ameren Companies’ payment of dividends in certain circumstances. Ameren Illinois’ articles of incorporation require its dividend payments on common stock to be based on ratios of common stock to total capitalization and other provisions with respect to certain operating expenses and accumulations of earned surplus. Additionally, Ameren has committed to the FERC to maintain a minimum of 30% equity in the capital structure at Ameren Illinois. Ameren Missouri and Ameren Illinois, as well as certain other nonregistrant Ameren subsidiaries, are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for any officer or director of a public utility, as defined in the Federal Power Act, to participate in the making or paying of any dividend from any funds “properly included in capital account.” The FERC has consistently interpreted the provision to allow dividends to be paid as long as (1) the source of the dividends is clearly disclosed, (2) the dividends are not excessive, and (3) there is no self-dealing on the part of corporate officials. At a minimum, Ameren believes that dividends can be paid by its subsidiaries that are public utilities from net income and from retained earnings. In addition, under Illinois law, Ameren Illinois and ATXI may not pay any dividend on their respective stock unless, among other things, their respective earnings and earned surplus are sufficient to declare and pay a dividend after provisions are made for reasonable and proper reserves, or unless Ameren Illinois or ATXI has specific authorization from the ICC. At December 31, 2021, the amount of restricted net assets of Ameren’s subsidiaries that may not be distributed to Ameren in the form of a loan or dividend was $3.8 billion. 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: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATXI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2021 2020 565 $ 24 — 99 494 66 9 30 Ameren Missouri and Ameren Illinois each have issued preferred stock, which provide for cumulative dividends. Each company’s board of directors considers the declaration of preferred stock dividends to shareholders of record on a certain date, stating the date on which the dividend is payable and the amount to be paid. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for further detail concerning the preferred stock issuances. 65 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 of the Ameren Companies by Moody’s and S&P effective on the date of this report: Moody’s S&P Ameren: Issuer/corporate credit rating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial paper . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Issuer/corporate credit rating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Secured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial paper . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Issuer/corporate credit rating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Secured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial paper . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATXI: Issuer credit rating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Baa1 Baa1 P-2 Baa1 A2 Baa1 P-2 A3 A1 A3 P-2 A2 A2 BBB+ BBB A-2 BBB+ A Not Rated A-2 BBB+ A BBB+ A-2 Not Rated Not Rated A credit rating is not a recommendation to buy, sell, or hold securities. It should be evaluated independently of any other rating. Ratings are subject to revision or withdrawal at any time by the rating organization. Collateral Postings Any weakening of our credit ratings may reduce access to capital and trigger additional collateral postings and prepayments. Such changes may also increase the cost of borrowing, resulting in an adverse effect on earnings. Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts, were $66 million for Ameren and Ameren Missouri and cash collateral posted by external parties were $22 million for Ameren and Ameren Illinois at December 31, 2021. A sub-investment-grade issuer or senior unsecured debt rating (below “Baa3” from Moody’s or below “BBB-” from S&P) at December 31, 2021, could have resulted in Ameren, Ameren Missouri, or Ameren Illinois being required to post additional collateral or other assurances for certain trade obligations amounting to $89 million, $61 million, and $28 million, respectively. Changes in commodity prices could trigger additional collateral postings and prepayments. Based on credit ratings at December 31, 2021, if market prices were 15% higher or lower than December 31, 2021 levels in the next 12 months and 20% higher or lower thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, or Ameren Illinois could be required to post an immaterial amount, compared to each company’s liquidity, of collateral or provide other assurances for certain trade obligations. 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. See Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for a discussion of existing and proposed environmental laws, including those that may address climate change, that affect, or may affect, our facilities, operations, and capital expenditures to comply with such laws. 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 of Ameren Missouri’s energy centers. Additionally, international agreements could lead to future federal or state legislation or regulations. In 2015, the United Nations Framework Convention on Climate Change reached consensus among approximately 190 nations on an agreement, known as the Paris 66 Agreement, that establishes a framework for greenhouse gas mitigation actions by all countries, with a goal of holding the increase in global average temperature to below 2 degrees Celsius above pre-industrial levels and an aspiration to limit the increase to 1.5 degrees Celsius. The Biden administration has announced a new policy commitment regarding a reduction in greenhouse gas emissions for the United States, but rulemaking to achieve such reductions has not yet been implemented. Actions taken to implement the Paris Agreement could result in future additional greenhouse gas reduction requirements in the United States. In addition, the Biden administration has announced plans to implement new climate change programs, including potential regulation of greenhouse gas emissions targeting the utility industry. We provide information regarding our sustainability initiatives through our website, including in our annual sustainability report, our responses to the annual climate change and water surveys conducted by CDP, and an ESG investor presentation. In addition, we issue an annual report in accordance with the Edison Electric Institute’s (EEI) and American Gas Association’s (AGA) ESG and sustainability-related reporting program. We also issue a periodic climate risk report and a report on our management of CCR. Additionally, we have posted a Task Force on Climate-related Financial Disclosures (TCFD) and Sustainability Accounting Standards Board (SASB) mapping of sustainability data. The reports may be updated at any time. The information on Ameren’s website, including the reports and documents mentioned in this paragraph, is not incorporated by reference into this report. 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. The continued effect of the 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. Although restrictions on social activities and nonessential businesses implemented in our service territories in 2020 have been relaxed, additional restrictions may be imposed in the future. We continue to assess the impacts the COVID-19 pandemic is having on our businesses, including but not limited to impacts on our liquidity; demand for residential, commercial, and industrial electric and natural gas services; changes in deferred payment arrangements for customers; bad debt expense; supply chain operations; the availability of our employees and contractors; counterparty credit; capital construction; infrastructure operations and maintenance; and pension valuations. 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 II, Item 8, of this report. Operations • • In 2021, our sales volumes, which have been, and continue to be, affected by the COVID-19 pandemic, among other things, increased compared to 2020, excluding the estimated effects of weather and customer energy-efficiency programs. While total sales volume levels were more comparable to pre-pandemic levels, there has been a shift in sales volumes by customer class, with an increase in residential sales, and a decrease in commercial and industrial sales. We expect total weather-normalized sales to return to 2019 levels by mid-2022 with the growth expected to be primarily over the second half of 2022. Because of their regulatory frameworks, Ameren Illinois’ and ATXI’s revenues are largely decoupled from changes in sales volumes. See the Results of Operations section above for additional information on our accounts receivable balances and Ameren Illinois’ electric and natural gas bad debt riders. Additionally, see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for information on Ameren Illinois’ reinstatement of customer disconnection and late fee charges for non-payment, accounting authority orders issued by the MoPSC related to Ameren Missouri's electric and natural gas services to allow Ameren Missouri to accumulate certain costs incurred, net of savings, and forgone customer late fee revenues related to the COVID-19 pandemic, with such amounts approved for recovery by the MoPSC in the December 2021 electric and natural gas service rate orders, and orders issued by the ICC in a service disconnection moratorium proceeding, which required Ameren Illinois to implement more flexible credit and collection practices and allowed for recovery of costs incurred related to the COVID-19 pandemic and forgone late fees. 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 15% of depreciation expense not recovered under the PISA, and earn a return at the applicable WACC for investments in renewable generation plant placed in service to comply with Missouri’s renewable energy standard. Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. The PISA and the RESRAM mitigate the effects of regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under the PISA and the remaining 15% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. 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. Both the rate increase 67 • • • • • limitation and the PISA are effective through December 2023, unless Ameren Missouri requests and the MoPSC approves an extension through December 2028. In 2018, the MoPSC issued an order approving Ameren Missouri’s MEEIA 2019 plan. The plan includes a portfolio of customer energy- efficiency 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 $70 million in 2022 and $75 million in 2023. The plan includes the continued use of the 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 are achieved for 2021 and 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. In December 2021, the MoPSC issued an order in Ameren Missouri’s 2021 electric service regulatory rate review, resulting in an increase of $220 million to Ameren Missouri’s annual revenue requirement for electric retail service. The order also changed annualized depreciation, regulatory asset and liability amortization amounts, and the base level of expenses for trackers. On an annualized basis, these changes reflect approximate increases in depreciation and amortization of $140 million and other operating and maintenance expenses of $40 million. As a result of the order, all off-system sales resulting from the High Prairie Renewable and Atchison Renewable energy centers will be included in the RESRAM beginning February 28, 2022. Prior to this change, 95% of these sales were included in the FAC and 5% were included in the RESRAM. The order also establishes a five-year recovery period for $61 million of certain costs associated with the Meramec Energy Center, which is expected to be retired in 2022. The new rates, base level of expenses, and amortizations will become effective on February 28, 2022. Ameren Illinois and ATXI use a forward-looking rate calculation with an annual revenue requirement reconciliation for each company’s electric transmission business. Based on expected rate base and the currently allowed 10.52% ROE, which includes a 50 basis point incentive adder for participation in an RTO, the revenue requirements included in 2022 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are $422 million and $195 million, respectively. These revenue requirements represent an increase in Ameren Illinois’ revenue requirement of $42 million and a decrease in ATXI’s revenue requirements 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 ATXI’s 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 of Appeals for the District of Columbia Circuit. Depending on the outcome of the appeal, the transmission rates charged during previous periods and the currently effective rates may be subject to change. Additionally, in March 2019, 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 in the allowed base ROE for participation in an RTO to 100 basis points from the current 50 basis points and revised the parameters for awarding incentives, while limiting the overall incentives to a cap of 250 basis points, among other things. In April 2021, the FERC issued a Supplemental Notice of Proposed Rulemaking, which proposes to modify the Notice of Proposed Rulemaking’s incentive for participation in an RTO by limiting this incentive for utilities that join an RTO to 50 basis points and only allowing them to earn the incentive for three years, among other things. If this proposal is included in a final rule, Ameren Illinois and ATXI would no longer be eligible for the 50 basis point RTO incentive adder, prospectively. The FERC is under no deadline to issue a final rule on this matter. Ameren is unable to predict the ultimate impact of any changes to the FERC’s incentives policy, or any further order on base ROE. A 50 basis point change in the FERC-allowed base ROE would affect Ameren’s and Ameren Illinois’ annual net income by an estimated $12 million and $8 million, respectively, based on each company’s 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 year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the year. Pursuant to 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 year’s actual recoverable costs, year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. For more information on the 68 • • • • • March 2021 ICC order, see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. By law, the decoupling 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. 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 ICC’s determination of performance metrics, Ameren Illinois anticipates filing an MYRP by mid-January 2023, with rates effective beginning in 2024. If Ameren 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. In December 2021, 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 of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. As of December 31, 2021, 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 $11 million change in Ameren’s and Ameren Illinois’ annual net income, based on Ameren Illinois’ 2022 projected year-end rate base, including electric energy-efficiency investments. Ameren Illinois’ allowed ROE for 2021 was based on an annual average of the monthly yields of the 30-year United States Treasury bonds of 2.05%. Pursuant to Illinois law, Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The allowed ROE on electric energy-efficiency investments can be increased or decreased by up to 200 basis points, depending on the achievement of annual energy savings goals. While the ICC has approved a plan for Ameren Illinois to invest approximately $100 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. Pursuant to the IETL, the planned annual investments in electric energy-efficiency programs will increase to approximately $120 million. Ameren Illinois expects to file a revised energy-efficiency plan with the ICC by early March 2022 to reflect the expected increased level of annual investments. Ameren Missouri’s next scheduled refueling and maintenance outage at its Callaway energy center is scheduled for the spring of 2022. Effective beginning with the fall 2020 refueling and maintenance outage, during a scheduled refueling, which occurs every 18 months, maintenance expenses are deferred as a regulatory asset and amortized until the completion of the next refueling and maintenance outage. During an outage, depending on the availability of its other generation sources and the market prices for power, Ameren Missouri’s purchased power costs may increase and the amount of excess power available for sale may decrease versus non-outage years. Changes in purchased power costs and excess power available for sale are included in the FAC, which results in limited impacts to earnings. In addition, Ameren Missouri may incur increased non-nuclear energy center maintenance costs in non-outage years. In August 2021, the United States Court of Appeals for the Eighth Circuit issued a decision that affirmed the United States District Court for the Eastern District of Missouri’s January 2017 liability ruling and the district court’s September 2019 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 has determined not to further appeal the court rulings and, in December 2021, filed a motion with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The district court is under no deadline to issue a ruling revising the remedy order. In January 2022, the MISO completed a preliminary assessment regarding potential impacts of the retirement to the regional electric power system, which indicated transmission upgrades and voltage support would be needed in advance of the retirement to address reliability concerns. In February 2022, Ameren Missouri expects to formally notify the MISO of its intent to retire the Rush Island Energy Center. Upon receipt of the formal notification, the MISO will conduct a final reliability assessment. The MISO must also separately approve the specific upgrades and transmission support required to address reliability concerns noted in the assessment. For additional information on the NSR and Clean Air Act litigation, see Note 14 – 69 Commitments and Contingencies under Part II, Item 8, of this report. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect 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. In February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center, including potential impacts on the reliability and cost of Ameren Missouri’s service to its customers, Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement, and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. The MoPSC staff is under no deadline to complete this review. As of December 31, 2021, 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 Ameren’s and Ameren Missouri’s 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. In January 2022, Ameren Missouri received notice of a proposed determination by the EPA that it has rejected Ameren Missouri’s requests to extend the timeline for operating certain impoundments located at the Sioux and Meramec energy centers. Compliance with the CCR Rule’s requirements for closure of the impoundments would be required 135 days after the EPA issues a final determination, which Ameren Missouri expects to be issued in the spring of 2022. 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 is in place. Ameren Missouri plans to retire the Meramec Energy Center in 2022, and is accelerating its construction plans to build a CCR Rule-compliant impoundment at the Sioux Energy Center to allow for continued operations. Additionally, Ameren Missouri is seeking a reliability determination from the MISO, which, if granted, would extend the deadline to comply with the requirement to close the impoundments and allow the energy centers to operate. Ameren Missouri does not expect that this matter will have a material adverse effect on its results of operations, financial position, or liquidity. The IETL established emission standards that became effective in September 2021. Ameren Missouri's natural gas-fired energy centers in Illinois will be 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, which could limit the operations of Ameren Missouri's five natural gas-fired energy centers located in the state of Illinois, and will result in the closure of one or more energy centers earlier than anticipated. 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 is reviewing the emission standards and the effect they may have on its generation strategy, including any increases in capital expenditures or operating costs, and changes to the useful lives of the five natural gas-fired energy centers. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect, among other things, the impact of these new emissions standards. 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, economic impacts of the COVID-19 pandemic, customer conservation efforts, the impacts of additional customer energy-efficiency programs, and increased customer use of increasingly cost-effective technological advances, 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 for efficiencies 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. • • • • We are observing inflationary pressures on the prices of commodities, labor, services, materials, and supplies. Ameren Missouri and Ameren Illinois are generally allowed to pass on to customers prudently incurred costs for fuel, purchased power, and natural gas supply. Additionally, for certain non-commodity cost changes, the use of trackers, riders, and formula ratemaking, as applicable, mitigates our exposure. The inflationary pressures 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. Liquidity and Capital Resources • Our customers’ payment for our services has been adversely affected by the COVID-19 pandemic. See the Results of Operations section above for additional information on our accounts receivable balances. Further, our liquidity and our capital expenditure plans could be adversely affected by other impacts resulting from the COVID-19 pandemic, including but not limited to potential impacts on our ability to access the capital markets on reasonable terms when needed and the timing of tax payments and the utilization of tax credits. We expect to make significant capital expenditures to improve our electric and natural gas utility infrastructure, however, disruptions to 70 • • • • • the capital markets and the ability of our suppliers and contractors to perform as required under their contracts could impact the execution of our capital investment strategy. For further discussion on the impacts to our ability to access the capital markets, see below. 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 Missouri’s electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $8.4 billion over the five-year period from 2022 through 2026, with expenditures largely recoverable under the PISA and the RESRAM. The planned investments in 2024 through 2026 are based on the assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA from December 2023 to December 2028. In connection with Ameren Missouri’s 2020 IRP, Ameren established a goal of achieving net-zero carbon emissions by 2050. Ameren is also targeting a 50% CO2 emission reduction by 2030 and an 85% reduction by 2040 from the 2005 level. In August 2021, the MoPSC issued an order affirming the plan’s compliance with Missouri law. The plan targets cleaner and more diverse sources of energy generation, including solar, wind, hydro, and nuclear power, and supports increased investment in new energy technologies. It also includes expanding renewable sources by adding 3,100 MWs of renewable generation by the end of 2030 and a total of 5,400 MWs of renewable generation by 2040. These amounts include 700 MWs related to the High Prairie Renewable and Atchison Renewable energy centers, which support Ameren Missouri’s compliance with the state of Missouri’s requirement of achieving 15% of native load sales from renewable energy sources that began in 2021. The plan also includes accelerating the retirement dates of the Sioux and Rush Island coal-fired energy centers to 2028 and 2039, respectively, the continued implementation of customer energy-efficiency programs, and the expectation that Ameren Missouri will seek NRC approval for an extension of the operating license for the Callaway Energy Center beyond its current 2044 expiration date. Additionally, the plan includes retiring the Meramec and Labadie coal-fired energy centers at the end of their useful lives (by 2022 and 2042, respectively). Ameren Missouri’s plan could be affected by, among other factors: Ameren Missouri’s 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, 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 Missouri’s ability to use such credits; the cost of wind, solar, and other renewable generation and storage technologies; changes in environmental regulations, including those related to carbon emissions; energy prices and demand; and Ameren Missouri’s ability to obtain necessary rights-of-way, easements, and transmission interconnection agreements at an acceptable cost and in a timely fashion. In December 2021, the MoPSC issued an order in Ameren Missouri’s 2021 electric service regulatory rate review, which, among other things, approved a change in the depreciable lives of the Sioux and Rush Island energy centers’ assets consistent with Ameren Missouri’s 2020 IRP. Due to the NSR and Clean Air Act Litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of this report, Ameren Missouri plans to retire the Rush Island Energy Center prior to the 2039 date discussed above. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect an accelerated retirement date for the Rush Island Energy Center and the impact of new emission standards pursuant to the IETL, as discussed in Note 14 – Commitments and Contingencies, among other things. The next integrated resource plan is expected to be filed in September 2023. Effective beginning August 2021, 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 of the Rush Island Energy Center due to the NSR and Clean Air Act Litigation discussed above, Ameren Missouri expects to seek approval from the MoPSC 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. In February 2022, Ameren Missouri entered into a build-transfer agreement with a subsidiary of Invenergy Renewables Global, LLC to acquire a 150-megawatt solar generation facility after construction. The facility is expected to be located in southeastern Illinois. The acquisition is subject to certain conditions, including the issuance of a certificate of convenience and necessity by the MoPSC, obtaining a MISO transmission interconnection agreement, and approval by the FERC. Ameren Missouri expects to file for a certificate of convenience and necessity with the MoPSC by mid-2022. 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, including an assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA from December 2023 to December 2028. Ameren’s and Ameren Missouri’s estimates exclude renewable generation investment opportunities of 1,200 MWs by 71 • • • • • • 2026, which are included in Ameren Missouri’s 2020 IRP, and additional 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. In April 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 February 2022, the MISO updated a list of projects under consideration for the first phase of the roadmap, and is expected to approve certain projects for the first phase by mid-2022. Expenditures that result from the MISO long-range transmission planning roadmap may cause adjustments to our estimated 2022 through 2026 capital expenditures. Environmental regulations, including those related to CO2 emissions, or other actions taken by the EPA or state regulators, or requirements that may result from the NSR and Clean Air Act Litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, 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 of Ameren Missouri’s coal and natural gas-fired energy centers. Ameren Missouri’s capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances as well as regulatory lag. The cost of Ameren Illinois’ purchased power and natural gas purchased for resale could increase. However, Ameren Illinois expects that these costs would be recovered from customers with no material adverse effect on its results of operations, financial position, or liquidity. Ameren’s and Ameren Missouri’s earnings could benefit from increased investment to comply with environmental regulations if those investments are reflected and recovered on a timely basis in customer rates. The Ameren Companies have multiyear credit agreements that cumulatively provide $2.3 billion of credit through December 2025, subject to a 364-day repayment term for Ameren Missouri and Ameren Illinois, with the option to seek incremental commitments to increase the cumulative credit provided to $2.7 billion. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for additional information regarding the Credit Agreements. 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 DRPlus 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 plans to issue approximately $300 million of equity each year from 2022 to 2026 in addition to issuances under the DRPlus and employee benefit plans. Ameren expects its equity to total capitalization to be about 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). As of December 31, 2021, Ameren had $133 million in tax benefits from federal and state income tax credit carryforwards and $66 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 Missouri’s High Prairie Renewable and Atchison Renewable energy centers, existing tax net operating losses, tax credit carryforwards, tax overpayments, and outstanding refunds. 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, for the month of February 2021, Ameren Missouri and Ameren Illinois had under-recovered costs under their PGA clauses and, for Ameren Missouri, under the FAC (Ameren Missouri - PGA $53 million, FAC $50 million; Ameren Illinois - PGA $221 million). Ameren Missouri’s PGA and FAC under-recoveries are designed to be collected from customers over 12 months beginning November 2021 and eight months beginning October 2021, respectively. In October 2021, the MoPSC issued an order allowing Ameren Missouri to extend the collection period for the cumulative PGA under-recovery as of August 2021, which includes the February 2021 under-recovery, from 12 months to 36 months beginning November 2021, to lessen the impact on customer rates. Ameren Illinois is collecting the PGA under-recovery over 18 months beginning April 2021, but the collection of the remaining balance may be extended at Ameren Illinois’ election to lessen the impact on customer rates. 72 The above items could have a material impact on our results of operations, financial position, and liquidity. Additionally, in the ordinary course of business, we evaluate strategies to enhance our results of operations, financial position, and liquidity. These strategies may include acquisitions, divestitures, opportunities to reduce costs or increase revenues, and other strategic initiatives to increase Ameren’s shareholder value. We are unable to predict which, if any, of these initiatives will be executed. The execution of these initiatives may have a material impact on our future results of operations, financial position, or liquidity. REGULATORY MATTERS See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. ACCOUNTING MATTERS Critical Accounting Estimates Preparation of the financial statements and related disclosures in compliance with GAAP requires the application of appropriate technical accounting rules and guidance, as well as the use of estimates. These estimates involve judgments regarding many factors that in and of themselves could materially affect the financial statements and disclosures. We have outlined below the critical accounting estimates that we believe are the most difficult, subjective, or complex. Any change in the assumptions or judgments applied in determining the following matters, among others, could have a material impact on future financial results. Accounting Estimate Uncertainties Affecting Application Regulatory Mechanisms and Cost Recovery We defer costs and recognize revenues that we intend to collect in future rates. • • • • • • Regulatory environment and external regulatory decisions and requirements Anticipated future regulatory decisions and our assessment of their impact The impact of prudence reviews, complaint cases, limitations on electric rate increases in Missouri, and opposition during the ratemaking process that may limit our ability to timely recover costs and earn a fair return on our investments Ameren Illinois’ assessment of and ability to estimate the current year’s electric distribution service costs to be reflected in revenues and recovered from customers in a subsequent year under performance-based formula ratemaking framework Ameren Illinois’ and ATXI’s assessment of and ability to estimate the current year’s electric transmission service costs to be reflected in revenues and recovered from customers in a subsequent year under the FERC ratemaking frameworks Ameren Missouri’s estimate of revenue recovery under the MEEIA plans Basis for Judgment The application of accounting guidance for rate-regulated businesses results in recording regulatory assets and liabilities. Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates. Regulatory assets are amortized as the incurred costs are recovered through customer rates. In some cases, we record regulatory assets before approval for recovery has been received from the applicable regulatory commission. We must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery. We base our conclusion on certain factors including, but not limited to, orders issued by our regulatory commissions, legislation, or historical experience, as well as discussions with legal counsel. If facts and circumstances lead us to conclude that a recorded regulatory asset is no longer probable of recovery or that plant assets are probable of disallowance, we record a charge to earnings, which could be material. Regulatory liabilities represent revenues received from customers to fund expected costs that have not yet been incurred or that are probable of future refunds to customers. We also recognize revenues for alternative revenue programs authorized by our regulators that allow for an automatic rate adjustment, are probable of recovery, and are collected within 24 months following the end of the annual period in which they are recognized. Under IEIMA performance-based formula ratemaking, effective through 2023, Ameren Illinois estimates its annual electric distribution revenue requirement for interim periods by using internal forecasted rate base and published forecasted data regarding the annual average of the monthly yields of the 30-year United States Treasury bonds. 73 Ameren Illinois estimates its annual revenue requirement as of December 31 of each year using that year’s actual operating results and assesses the probability of recovery from or refund to customers that the ICC will order at the end of the following year. Variations in investments made or orders by the ICC or courts can result in a subsequent change in Ameren Illinois’ estimate. Ameren Illinois and ATXI follow a similar process for their FERC rate-regulated electric transmission businesses. Ameren Missouri estimates lost electric margins resulting from its MEEIA customer energy-efficiency programs, which are subsequently recovered through the MEEIA rider. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for a description of our regulatory mechanisms and quantification of these assets or liabilities for each of the Ameren Companies. The following table reflects the gain and other comprehensive income, which would be offset by the removal of regulatory assets and liabilities and an increase in accumulated other comprehensive income, that would have resulted if accounting guidance for rate-regulated businesses had been eliminated as of December 31, 2021: Gains . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other comprehensive income (before taxes) - pension and other postretirement benefit plan activity . . . . Ameren Ameren Missouri Ameren Illinois 3,562 $ 791 2,362 $ 399 1,104 392 Accounting Estimate Benefit Plan Accounting Based on actuarial calculations, we accrue costs of providing future employee benefits for the benefit plans we offer our employees. See Note 10 – Retirement Benefits under Part II, Item 8, of this report. Uncertainties Affecting Application • • • • • • • • • Valuation inputs and assumptions used in the fair value measurements of plan assets, excluding those inputs that are readily observable Discount rate Cash balance plan interest crediting rate on certain plans Future compensation increase assumption Health care cost trend rates Assumptions on the timing of employee retirements, terminations, benefit payments, and mortality Ability to recover certain benefit plan costs from our customers Changing market conditions that may affect investment and interest rate environments Future rate of return on pension and other plan assets Basis for Judgment Ameren has defined benefit pension plans covering substantially all of its employees and has postretirement benefit plans covering non-union employees hired before October 2015 and union employees hired before January 2020. Our ultimate selection of the discount rate, health care trend rate, and expected rate of return on pension and other postretirement benefit plan assets is based on our consistent application of assumption-setting methodologies and our review of available historical, current, and projected rates, as applicable. The following table reflects the sensitivity of Ameren’s pension and postretirement plans to potential changes in key assumptions for the year ended December 31, 2021: Pension Benefits Postretirement Benefits 0.25% decrease in discount rate . . . . . . . . . . . . . . . . . $ 0.25% decrease in return on assets . . . . . . . . . . . . . . . 0.25% increase in future compensation . . . . . . . . . . . . $ 18 11 5 188 $ — 21 Net Periodic Benefit Cost Projected Pension Benefit Obligation Net Periodic Benefit Cost Projected Postretirement Benefit Obligation $ 3 3 — 38 — — 74 Accounting Estimate Accounting for Contingencies Uncertainties Affecting Application We make judgments and estimates in the recording and the disclosing of liabilities for claims, litigation, environmental remediation, the actions of various regulatory agencies, or other matters that occur in the normal course of business. We record a loss contingency when it is probable that a liability has been incurred and that the amount of the loss can be reasonably estimated. • • • • • Estimating financial impact of events Estimating likelihood of various potential outcomes Regulatory and political environments and requirements Outcome of legal proceedings, settlements, or other factors Changes in regulation, expected scope of work, technology, or timing of environmental remediation Basis for Judgment The determination of a loss contingency requires significant judgment as to the expected outcome of the contingency in future periods. In making the determination as to the amount of potential loss and the probability of loss, we consider the nature of the litigation, the claim or assessment, opinions or views of legal counsel, and the expected outcome of potential litigation, among other things. If no estimate is better than another within our range of estimates, we record as our best estimate of a loss the minimum value of our estimated range of outcomes. As additional information becomes available, we reassess the potential liability related to the contingency and revise our estimates. The amount recorded for any contingency may differ from actual costs incurred when the contingency is resolved. Contingencies are normally resolved over long periods of time. In our evaluation of legal matters, management consults with legal counsel and relies on analysis of relevant case law and legal precedents. See Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, and Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for information on the Ameren Companies’ contingencies. Accounting Estimate Accounting for Income Taxes We record a provision for income taxes, deferred tax assets and liabilities, and a valuation allowance against net deferred tax assets, if any. See Note 12 – Income Taxes under Part II, Item 8, of this report. Uncertainties Affecting Application • • • • • • Changes in business, industry, laws, technology, or economic and market conditions affecting forecasted financial condition and/or results of operations Estimates of the amount and character of future taxable income and forecasted use of our tax credit carryforwards Enacted tax rates applicable to taxable income in years in which temporary differences are recovered or settled Effectiveness of implementing tax planning strategies Changes in income tax laws, including amounts subject to income tax, and the regulatory treatment of any tax reform changes Results of audits and examinations by taxing authorities 75 Basis for Judgment The reporting of tax-related assets and liabilities requires the use of estimates and significant management judgment. Deferred tax assets and liabilities are recorded to represent future effects on income taxes for temporary differences between the basis of assets for financial reporting and tax purposes. Although management believes that current estimates for deferred tax assets and liabilities are reasonable, actual results could differ from these estimates for a variety of reasons, including: a change in forecasted financial condition and/or results of operations; changes in income tax laws, enacted tax rates or amounts subject to income tax; the form, structure, and timing of asset or stock sales or dispositions; changes in the regulatory treatment of any tax reform benefits; and changes resulting from audits and examinations by taxing authorities. Valuation allowances against deferred tax assets are recorded when management concludes it is more likely than not such asset will not be realized in future periods. Accounting for income taxes also requires that only tax benefits for positions taken or expected to be taken on tax returns that meet the more-likely-than-not recognition threshold can be recognized or continue to be recognized. Management evaluates each position solely on the technical merits and facts and circumstances of the position, assuming that the position will be examined by a taxing authority that has full knowledge of all relevant information. Significant judgment is required to determine recognition thresholds and the related amount of tax benefits to be recognized. At each period end, and as new developments occur, management reevaluates its tax positions. See Note 12 – Income Taxes under Part II, Item 8, of this report for the amount of deferred income taxes recorded at December 31, 2021. Accounting Estimate Uncertainties Affecting Application Accounting for Asset Retirement Obligations We record the estimated fair value of legal obligations associated with the retirement of tangible long-lived assets. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. • • • • Discount rates Cost escalation rates Changes in regulation, expected scope of work, technology, or timing of environmental remediation Estimates as to the probability, timing, or amount of cash expenditures associated with AROs Basis for Judgment We record the estimated fair value of legal obligations associated with the retirement of tangible long-lived assets in the period in which the liabilities are incurred and capitalize a corresponding amount as part of the book value of the related long-lived asset. In subsequent periods, we adjust AROs for accretion and changes in the estimated fair values of the obligations, with a corresponding increase or decrease in the asset book value for the fair value changes. We estimate the fair value of our AROs using present value techniques, in which we make various assumptions about discount rates and cost escalation rates. In addition, these estimates include assumptions of the probability, timing, and amount of cash expenditures to settle the ARO, and are based on currently available technology. Ameren and Ameren Missouri have recorded AROs for retirement costs associated with decommissioning of Ameren Missouri’s Callaway and wind renewable energy centers, certain Ameren Missouri solar energy centers, CCR facilities, and river structures at certain energy centers used for unloading coal and circulating water systems. Additionally, Ameren, Ameren Missouri, and Ameren Illinois have recorded AROs for retirement costs associated with asbestos removal and the disposal of certain transformers. See Note 15 – Supplemental Information under Part II, Item 8, of this report for the amount of AROs recorded at December 31, 2021. A significant portion of Ameren’s and Ameren Missouri’s AROs relate to the decommissioning of Ameren Missouri’s Callaway Energy Center. Changes in key assumptions could materially affect the decommissioning obligation. The following table reflects the sensitivity of potential changes in key assumptions to Ameren Missouri’s Callaway Energy Center decommissioning obligation as of December 31, 2021: Change in Callaway Energy Center’s Key ARO Assumptions Increase (Decrease) to ARO Discount rate decreased by 0.10% . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Cost escalation rate increased by 0.25% . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in the estimated decommissioning costs by 10% . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Two-year deferral in timing of cash expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 63 94 (8) Impact of New Accounting Pronouncements See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK Market risk is the risk of changes in value of a physical asset or a financial instrument, derivative or nonderivative, caused by fluctuations in market variables such as interest rates, commodity prices, and equity security prices. A derivative is a contract whose value is dependent 76 on, or derived from, the value of some underlying asset or index. The following discussion of our risk management activities includes forward- looking statements that involve risks and uncertainties. Actual results could differ materially from those projected in the forward-looking statements. We handle market risks in accordance with established policies, which may include entering into various derivative transactions. In the normal course of business, we also face risks that are either nonfinancial or nonquantifiable. Such risks, principally business, legal, and operational risks, are not part of the following discussion. Our risk management objectives are to optimize our physical generating assets and to pursue market opportunities within prudent risk parameters. Our risk management policies are set by a risk management steering committee, which is composed of senior-level Ameren officers, with Ameren board of directors’ oversight. Interest Rate Risk We are exposed to market risk through changes in interest rates associated with: • • • • short-term variable-rate debt; fixed-rate debt; United States Treasury bonds; and the discount rate applicable to asset retirement obligations, goodwill, and defined pension and postretirement benefit plans. We manage our interest rate exposure by controlling the amount of debt instruments within our total capitalization portfolio and by monitoring the effects of market changes on interest rates. For defined pension and postretirement benefit plans, we control the duration and the portfolio mix of our plan assets. See Note 1 – Summary of Significant Accounting Policies and Note 10 – Retirement Benefits under Part II, Item 8, of this report for additional information related to asset retirement obligations, goodwill, and the defined pension and postretirement benefit plans. The estimated increase in our annual interest expense and decrease in net income if interest rates were to increase by 100 basis points on variable-rate debt outstanding at December 31, 2021 is immaterial. The allowed ROE under Ameren Illinois’ IEIMA electric distribution service and its electric energy-efficiency investments formula ratemaking recovery mechanisms is based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. Therefore, Ameren Illinois’ annual ROE for its electric distribution business is directly correlated to the yields on such bonds, which are outside of Ameren Illinois’ control. Ameren Illinois expects to use the current IEIMA formula framework to establish annual customer rates effective through 2023 and reconcile the related revenue requirements. 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 $11 million change in Ameren’s and Ameren Illinois’ annual net income, based on Ameren Illinois’ 2022 projected year-end rate base, including electric energy-efficiency investments. Interest rate levels also influence the ROE allowed by our regulators in our other ratemaking jurisdictions, as well as the carrying costs associated with certain regulatory assets and liabilities. Credit Risk Credit risk represents the loss that would be recognized if counterparties should fail to perform as contracted. Exchange-traded contracts are supported by the financial and credit quality of the clearing members of the respective exchanges and carry only a nominal credit risk. In all other transactions, we are exposed to credit risk in the event of nonperformance by the counterparties to the transaction. See Note 7 – Derivative Financial Instruments under Part II, Item 8, of this report for information on the potential loss on counterparty exposure as of December 31, 2021. Our revenues are primarily derived from sales or delivery of electricity and natural gas to customers in Missouri and Illinois. Our physical and financial instruments are subject to credit risk consisting of trade accounts receivables and executory contracts with market risk exposures. The risk associated with trade receivables is mitigated by the large number of customers in a broad range of industry groups who make up our customer base. At December 31, 2021, no nonaffiliated customer represented more than 10% of our accounts receivable. Additionally, Ameren Illinois faces risks associated with the purchase of receivables. The Illinois Public Utilities Act requires Ameren Illinois to establish electric utility consolidated billing and purchase of receivables services. At the option of an alternative retail electric supplier, Ameren Illinois may be required to purchase the supplier’s receivables relating to Ameren Illinois’ distribution customers who elected to receive power supply from the alternative retail electric supplier. When that option is selected, Ameren Illinois produces consolidated bills for the applicable retail customers to reflect charges for electric distribution and purchased receivables. As of December 31, 2021, Ameren Illinois’ balance of purchased accounts receivable associated with the utility consolidated billing and purchase of receivables services was $27 million. The risk associated with Ameren Illinois’ electric and natural gas trade receivables is also mitigated by a rider that allows Ameren Illinois to recover the difference between its actual net bad debt write-offs under GAAP and the amount of net bad debt write-offs included in its base rates. Ameren Missouri and Ameren Illinois continue to monitor the impact of the COVID-19 pandemic on customer collections and customer account balances. Ameren Missouri and Ameren Illinois make adjustments to their respective allowance for doubtful accounts as 77 deemed necessary to ensure that such allowances are adequate to cover estimated uncollectible customer account balances. See Results of Operations in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report for more information on Ameren’s, Ameren Missouri’s, and Ameren Illinois’ accounts receivable balances that were 30 days or greater past due or that were a part of a deferred payment arrangement as of December 31, 2021. In addition, for information regarding Ameren Illinois’ suspension and reinstatement of customer disconnection activities and late fee charges for nonpayment, see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. Investment Price Risk Plan assets of the pension and postretirement trusts, the nuclear decommissioning trust fund, and company-owned life insurance contracts include equity and debt securities. The equity securities are exposed to price fluctuations in equity markets. The debt securities are exposed to changes in interest rates. Our costs for providing defined benefit retirement and postretirement benefit plans are dependent upon a number of factors, including the rate of return on plan assets. Ameren manages plan assets in accordance with the “prudent investor” guidelines contained in ERISA. Ameren’s goal is to ensure that sufficient funds are available to provide benefits at the time they are payable, while also maximizing total return on plan assets and minimizing expense volatility consistent with its tolerance for risk. Ameren delegates investment management to specialists. Where appropriate, Ameren provides the investment manager with guidelines that specify allowable and prohibited investment types. Ameren regularly monitors manager performance and compliance with investment guidelines. The expected return on plan assets assumption is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Projected rates of return for each asset class are estimated after an analysis of historical experience, future expectations, and the volatility of the various asset classes. After considering the target asset allocation for each asset class, we adjust the overall expected rate of return for the portfolio for historical and expected experience of active portfolio management results compared with benchmark returns, and for the effect of expenses paid from plan assets. Contributions to the plans and future costs could increase materially if we do not achieve pension and postretirement asset portfolio investment returns equal to or in excess of our 2022 assumed return on plan assets of 6.50%. Ameren Missouri also maintains a trust fund, as required by the NRC and Missouri law, to fund certain costs of nuclear plant decommissioning. As of December 31, 2021, this fund was invested in domestic equity securities (71%) and debt securities (28%). By maintaining a portfolio that includes long-term equity investments, Ameren Missouri seeks to maximize the returns to be used to fund nuclear decommissioning costs within acceptable parameters of risk. Ameren Missouri actively monitors the portfolio by benchmarking the performance of its investments against certain indices and by maintaining and periodically reviewing established target allocation percentages of the trust assets to various investment options. Ameren Missouri’s exposure to equity price market risk is in large part mitigated because Ameren Missouri is currently allowed to recover its decommissioning costs, which would include unfavorable investment results, through electric rates. Additionally, Ameren and Ameren Illinois have company-owned life insurance contracts with net asset values of $169 million and $8 million, respectively, as of December 31, 2021. To the extent not recovered through rates, changes in the market values of these contracts are reflected in earnings. Commodity Price Risk Ameren Missouri’s and Ameren Illinois’ electric and natural gas distribution businesses’ exposure to changing market prices for commodities is in large part mitigated by the fact that there are cost recovery mechanisms in place. These cost recovery mechanisms allow Ameren Missouri and Ameren Illinois to pass on to retail customers prudently incurred costs for fuel, purchased power, and natural gas supply. Ameren Missouri’s and Ameren Illinois’ strategy is designed to reduce the effect of market fluctuations for their customers. The effects of price volatility cannot be eliminated. However, procurement and sales strategies involve risk management techniques and instruments, as well as the management of physical assets. Ameren Missouri has a FAC that allows it to recover or refund, through customer rates, 95% of the variance in net energy costs from the amount set in base rates without a traditional regulatory rate review, subject to MoPSC prudence reviews. Ameren Missouri remains exposed to the remaining 5% of such changes. Ameren Illinois has cost recovery mechanisms for power purchased, capacity, zero emission credit, and renewable energy credit costs and expects full recovery of such costs. Ameren Illinois is required to serve as the provider of last resort for electric customers in its service territory who have not chosen an alternative retail electric supplier. In 2021, Ameren Illinois procured power on behalf of its customers for 23% of its total kilowatthour sales. Ameren Illinois purchases energy and capacity through the MISO and through bilateral contracts resulting 78 from IPA procurement events. The IPA has proposed and the ICC has approved multiple procurement events covering portions of years through 2024 for capacity and energy. Ameren Illinois has also entered into ICC-approved contracts for zero emission credits through 2026 and for renewable energy credits with various terms, including contracts with a 20-year term ending 2032, and contracts entered into beginning in 2018 through 2021 with 15-year terms commencing on the date of first renewable energy credit delivery. Ameren Illinois does not generate earnings based on the resale of power or purchase of zero emission credits or renewable energy credits but rather on the delivery of the energy. Ameren Missouri and Ameren Illinois have PGA clauses that permit costs incurred for natural gas to be recovered directly from utility customers without a traditional regulatory rate review, subject to prudence reviews. The following table presents, as of December 31, 2021, the percentages of the projected required supply of coal and coal transportation for Ameren Missouri’s coal-fired energy centers, nuclear fuel for Ameren Missouri’s Callaway Energy Center, natural gas for Ameren Missouri’s and Ameren Illinois’ retail distribution, and purchased power for Ameren Illinois that are price-hedged over the period 2022 through 2026. The projected required supply of these commodities could be significantly affected by changes in our assumptions about customer demand for electricity and natural gas supplied by us and inventory levels, as well as Ameren Missouri’s generation output, among other matters. Ameren: Coal(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Coal transportation(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear fuel(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for distribution(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power for Ameren Illinois(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Coal(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Coal transportation(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear fuel(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for distribution(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Natural gas for distribution(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2022 2023 2024 – 2026 99 % 100 100 94 69 99 % 100 100 96 93 % 69 51 % 100 97 37 34 51 % 100 97 40 36 % 34 22 % 32 80 11 11 22 % 32 80 19 9 % 11 (a) (b) (c) (d) Ameren Missouri has agreements in place to purchase and transport coal to its energy centers. While Ameren Missouri has minimum purchase obligations associated with these agreements, the majority of these agreements are not associated with any specific coal-fired energy center. The Callaway Energy Center has historically required refueling at 18-month intervals. As there is no refueling and maintenance outage scheduled to occur during 2024, there are also no nuclear fuel deliveries anticipated to occur in this year. Represents the percentage of natural gas price-hedged for peak winter season of November through March. The year 2022 represents January 2022 through March 2022. The year 2023 represents November 2022 through March 2023. This continues each successive year through March 2026. Represents the percentage of purchased power price-hedged for fixed-price residential and nonresidential customers with less than 150 kilowatts of demand. Our exposure to commodity price risk for construction and maintenance activities is related to changes in market prices for metal commodities and to labor availability. Also see Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for additional information. Commodity Supplier Risk The use of low-sulfur coal is part of Ameren Missouri’s environmental compliance strategy. Ameren Missouri has agreements with multiple suppliers to purchase low-sulfur coal through 2025 to comply with environmental regulations. Disruptions to the deliveries of low- sulfur coal from a supplier could compromise Ameren Missouri’s ability to operate in compliance with emission standards. The suppliers of low-sulfur coal are limited. In addition, low-sulfur coal suppliers have experienced financial hardships in recent years and could continue to experience financial hardships that could impact their ability to deliver shipments of low-sulfur coal in accordance with existing supply contracts. If Ameren Missouri were to experience a temporary disruption of low-sulfur coal deliveries that caused it to exhaust its existing inventory, and if other sources of low-sulfur coal were not available, Ameren Missouri would have to use its existing emission allowances, purchase emission allowances, and reduce generation to achieve compliance with environmental regulations. Ameren Missouri would then need to purchase power necessary to meet demand. Currently, the Callaway Energy Center has a single NRC-licensed supplier able to provide fuel assemblies to the Callaway Energy Center. Ameren Missouri is pursuing a program to qualify an alternate NRC-licensed supplier, and expects to obtain NRC approval in 2023. 79 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Ameren Corporation Opinions on the Financial Statements and Internal Control over Financial Reporting We have audited the accompanying consolidated balance sheets of Ameren Corporation and its subsidiaries (the “Company”) as of December 31, 2021 and 2020, and the related consolidated statements of income and comprehensive income, of shareholders’ equity and of cash flows for each of the three years in the period ended December 31, 2021, including the related notes and financial statement schedules listed in the index appearing under Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO. Basis for Opinions The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Report on Internal Control over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions. Definition and Limitations of Internal Control over Financial Reporting A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. 80 Critical Audit Matters The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. Accounting for the Effects of Regulation As described in Notes 1 and 2 to the consolidated financial statements, the Company has operations that are subject to the decisions and requirements of its regulators. As disclosed by management, the Company’s use of accounting guidance for rate-regulated businesses results in recording regulatory assets and liabilities for certain transactions that management expects will be recovered from or refunded to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. As of December 31, 2021, there were approximately $1.6 billion of regulatory assets and approximately $6.0 billion of regulatory liabilities. In some cases, management records regulatory assets before approval for recovery has been received from the applicable regulatory commission. Management must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery. Additionally, management recognizes revenue for alternative revenue programs that allow for an automatic rate adjustment, are probable of recovery, and are collected within 24 months of the end of the annual period in which they are recognized. Management’s conclusions are based on certain factors including, but not limited to, regulatory commission orders, legislation, or historical experience, as well as management’s discussions with legal counsel. The principal considerations for our determination that performing procedures relating to accounting for the effects of regulation is a critical audit matter are the significant judgment by management when accounting for (i) new or existing regulatory assets or liabilities that were impacted by updates in regulatory commission orders, legislation, historical experience, or management’s discussions with legal counsel, (ii) the probability of recovery of regulatory assets and refund of regulatory liabilities recorded before approval has been received from the regulator, and (iii) regulatory mechanisms meeting the alternative revenue program criteria, which in turn led to a high degree of auditor judgment, subjectivity, and effort when performing audit procedures and evaluating audit evidence obtained related to management’s application of regulatory accounting, assessment of probability of recovery of regulatory assets and refund of regulatory liabilities, and expected timing of collection within 24 months of the end of the annual period in which mechanisms are recognized. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s implementation and application of new or existing regulatory assets or liabilities, including controls related to evaluating the probability of recovery of regulatory assets and refund of regulatory liabilities, and alternative revenue programs. These procedures also included, among others, (i) testing calculations of new and existing regulatory assets or liabilities by comparison to provisions and formulas outlined in regulatory commission orders or legislation, (ii) evaluating management’s assessment of the probability of recovery of regulatory assets and refund of regulatory liabilities, and (iii) evaluating management’s assessment of regulatory mechanisms meeting the alternative revenue program criteria and the expected timing of collection within 24 months of the end of the annual period in which mechanisms are recognized. /s/ PricewaterhouseCoopers LLP St. Louis, Missouri February 22, 2022 We have served as the Company’s auditor since at least 1932. We have not been able to determine the specific year we began serving as auditor of the Company. 81 Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Union Electric Company Opinion on the Financial Statements We have audited the accompanying balance sheets of Union Electric Company (the “Company”) as of December 31, 2021 and 2020, and the related statements of income, of shareholders’ equity and of cash flows for each of the three years in the period ended December 31, 2021, including the related notes and financial statement schedule listed in the index appearing under Item 15(a)(2) (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021 in conformity with accounting principles generally accepted in the United States of America. Basis for Opinion These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits of these financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Critical Audit Matters The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. Accounting for the Effects of Regulation As described in Notes 1 and 2 to the financial statements, the Company has operations that are subject to the decisions and requirements of its regulators. As disclosed by management, the Company’s use of accounting guidance for rate-regulated businesses results in recording regulatory assets and liabilities for certain transactions that management expects will be recovered from or refunded to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. As of December 31, 2021, there were approximately $0.7 billion of regulatory assets and approximately $3.4 billion of regulatory liabilities. In some cases, management records regulatory assets before approval for recovery has been received from the applicable regulatory commission. Management must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery. Management’s conclusions are based on certain factors including, but not limited to, regulatory commission orders, legislation, or historical experience, as well as management’s discussions with legal counsel. The principal considerations for our determination that performing procedures relating to accounting for the effects of regulation is a critical audit matter are the significant judgment by management when accounting for (i) new or existing regulatory assets or liabilities that were impacted by updates in regulatory commission orders, legislation, historical experience, or management’s discussions with legal counsel, and (ii) the probability of recovery of regulatory assets and refund of regulatory liabilities recorded before approval has been received from the regulator, which in turn led to a high degree of auditor judgment, subjectivity, and audit effort when performing audit procedures and 82 evaluating audit evidence obtained related to management’s application of regulatory accounting and assessment of probability of recovery of regulatory assets and refund of regulatory liabilities. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the financial statements. These procedures included testing the effectiveness of controls relating to management’s implementation and application of new or existing regulatory assets or liabilities, including controls related to evaluating the probability of recovery of regulatory assets and refund of regulatory liabilities. These procedures also included, among others, (i) testing calculations of new and existing regulatory assets or liabilities by comparison to provisions and formulas outlined in regulatory commission orders, and (ii) evaluating management’s assessment of the probability of recovery of regulatory assets and refund of regulatory liabilities. /s/ PricewaterhouseCoopers LLP St. Louis, Missouri February 22, 2022 We have served as the Company’s auditor since at least 1932. We have not been able to determine the specific year we began serving as auditor of the Company. 83 Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Ameren Illinois Company Opinion on the Financial Statements We have audited the accompanying balance sheets of Ameren Illinois Company (the “Company”) as of December 31, 2021 and 2020, and the related statements of income, of shareholders’ equity and of cash flows for each of the three years in the period ended December 31, 2021, including the related notes and financial statement schedule listed in the index appearing under Item 15(a)(2) (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021 in conformity with accounting principles generally accepted in the United States of America. Basis for Opinion These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits of these financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Critical Audit Matters The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. Accounting for the Effects of Regulation As described in Notes 1 and 2 to the financial statements, the Company has operations that are subject to the decisions and requirements of its regulators. As disclosed by management, the Company’s use of accounting guidance for rate-regulated businesses results in recording regulatory assets and liabilities for certain transactions that management expects will be recovered from or refunded to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. As of December 31, 2021, there were approximately $0.9 billion of regulatory assets and approximately $2.4 billion of regulatory liabilities. In some cases, management records regulatory assets before approval for recovery has been received from the applicable regulatory commission. Management must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery. Additionally, management recognizes revenue for alternative revenue programs that allow for an automatic rate adjustment, are probable of recovery, and are collected within 24 months of the end of the annual period in which they are recognized. Management’s conclusions are based on certain factors including, but not limited to, regulatory commission orders, legislation, or historical experience, as well as management’s discussions with legal counsel. The principal considerations for our determination that performing procedures relating to accounting for the effects of regulation is a critical audit matter are the significant judgment by management when accounting for (i) new or existing regulatory assets or liabilities that were impacted by updates in regulatory commission orders, legislation, historical experience, or management’s discussions with legal counsel, (ii) the probability of recovery of regulatory assets and refund of regulatory liabilities recorded before approval has been received from the regulator, and (iii) regulatory mechanisms meeting the alternative revenue program criteria, which in turn led to a high degree of auditor 84 judgment, subjectivity, and effort when performing audit procedures and evaluating audit evidence obtained related to management’s application of regulatory accounting, assessment of probability of recovery of regulatory assets and refund of regulatory liabilities, and expected timing of collection within 24 months of the end of the annual period in which mechanisms are recognized. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the financial statements. These procedures included testing the effectiveness of controls relating to management’s implementation and application of new or existing regulatory assets or liabilities, including controls related to evaluating the probability of recovery of regulatory assets and refund of regulatory liabilities, and alternative revenue programs. These procedures also included, among others, (i) testing calculations of new and existing regulatory assets or liabilities by comparison to provisions and formulas outlined in regulatory commission orders or legislation, (ii) evaluating management’s assessment of the probability of recovery of regulatory assets and refund of regulatory liabilities, and (iii) evaluating management’s assessment of regulatory mechanisms meeting the alternative revenue program criteria and the expected timing of collection within 24 months of the end of the annual period in which mechanisms are recognized. /s/ PricewaterhouseCoopers LLP St. Louis, Missouri February 22, 2022 We have served as the Company’s auditor since 1998. 85 AMEREN CORPORATION CONSOLIDATED STATEMENT OF INCOME AND COMPREHENSIVE INCOME (In millions, except per share amounts) Operating Revenues: Electric Natural gas Total operating revenues Operating Expenses: Fuel Purchased power Natural gas purchased for resale Other operations and maintenance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income, Net Interest Charges Income Before Income Taxes Income Taxes Net Income Less: Net Income Attributable to Noncontrolling Interests Net Income Attributable to Ameren Common Shareholders Net Income Other Comprehensive Income, Net of Taxes Pension and other postretirement benefit plan activity, net of income taxes of $4, $5, and $1, respectively Comprehensive Income Less: Comprehensive Income Attributable to Noncontrolling Interests Comprehensive Income Attributable to Ameren Common Shareholders Earnings per Common Share – Basic Earnings per Common Share – Diluted Weighted-average Common Shares Outstanding – Basic Weighted-average Common Shares Outstanding – Diluted $ $ $ $ $ $ Year Ended December 31, 2020 2021 2019 5,297 1,097 6,394 581 606 442 1,774 1,146 512 5,061 1,333 202 383 1,152 157 995 5 990 $ $ 4,911 883 5,794 490 513 272 1,661 1,075 483 4,494 1,300 151 419 1,032 155 877 6 871 $ $ 4,981 929 5,910 535 556 331 1,745 995 481 4,643 1,267 130 381 1,016 182 834 6 828 995 $ 877 $ 834 14 1,009 5 1,004 3.86 3.84 256.3 257.6 $ $ $ 16 893 6 887 3.53 3.50 247.0 248.7 $ $ $ 5 839 6 833 3.37 3.35 245.6 247.1 The accompanying notes are an integral part of these consolidated financial statements. 86 AMEREN CORPORATION CONSOLIDATED BALANCE SHEET (In millions, except per share amounts) Current Assets: ASSETS Cash and cash equivalents Accounts receivable – trade (less allowance for doubtful accounts of $29 and $50, respectively) Unbilled revenue Miscellaneous accounts receivable Inventories Current regulatory assets Other current assets Total current assets Property, Plant, and Equipment, Net Investments and Other Assets: Nuclear decommissioning trust fund Goodwill Regulatory assets Pension and other postretirement benefits Other assets Total investments and other assets TOTAL ASSETS LIABILITIES AND EQUITY Current Liabilities: Current maturities of long-term debt Short-term debt Accounts and wages payable Interest accrued Current regulatory liabilities Other current liabilities Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes and investment tax credits, net Regulatory liabilities Asset retirement obligations Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 9, and 14) Shareholders’ Equity: Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 257.7 and 253.3, respectively Other paid-in capital, principally premium on common stock Retained earnings Accumulated other comprehensive income (loss) Total shareholders’ equity Noncontrolling Interests Total equity TOTAL LIABILITIES AND EQUITY December 31, 2021 2020 $ $ $ $ 8 434 301 85 592 319 229 1,968 29,261 1,159 411 1,289 756 891 4,506 35,735 505 545 1,095 123 113 445 2,826 12,562 3,499 5,848 757 414 10,518 3 6,502 3,182 13 9,700 129 9,829 35,735 $ $ $ $ 139 415 269 65 521 109 135 1,653 26,807 982 411 1,100 288 789 3,570 32,030 8 490 958 114 121 489 2,180 11,078 3,211 5,282 696 503 9,692 3 6,179 2,757 (1) 8,938 142 9,080 32,030 The accompanying notes are an integral part of these consolidated financial statements. 87 AMEREN CORPORATION CONSOLIDATED STATEMENT OF CASH FLOWS (In millions) Cash Flows From Operating Activities: Net income Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization Amortization of nuclear fuel Amortization of debt issuance costs and premium/discounts Deferred income taxes and investment tax credits, net Allowance for equity funds used during construction Stock-based compensation costs Other Changes in assets and liabilities: Receivables Inventories Accounts and wages payable Taxes accrued Regulatory assets and liabilities Assets, other Liabilities, other Pension and other postretirement benefits Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Wind generation expenditures Nuclear fuel expenditures Purchases of securities – nuclear decommissioning trust fund Sales and maturities of securities – nuclear decommissioning trust fund Purchase of bonds Proceeds from sale of remarketed bonds Other Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends paid to noncontrolling interest holders Short-term debt, net Maturities of long-term debt Issuances of long-term debt Issuances of common stock Redemptions of Ameren Illinois preferred stock Employee payroll taxes related to stock-based compensation Debt issuance costs Other Net cash provided by financing activities Net change in cash, cash equivalents, and restricted cash Cash, cash equivalents, and restricted cash at beginning of year Cash, cash equivalents, and restricted cash at end of year Cash Paid (Refunded) During the Year: Interest (net of $17, $16, and $20 capitalized, respectively) Income taxes, net Year Ended December 31, 2020 2021 2019 $ 995 $ 877 $ 834 1,219 58 23 156 (43) 22 19 (74) (71) 28 1 (439) (126) (74) (33) 1,661 (2,954) (525) (44) (452) 439 — — 8 (3,528) (565) (5) 55 (8) 1,997 308 (13) (17) (18) (13) 1,721 (146) 301 155 426 (1) $ $ 1,085 68 22 148 (32) 21 22 (47) (25) 40 34 (254) (83) (111) (38) 1,727 (2,669) (564) (66) (224) 183 — — 11 (3,329) (494) (6) 50 (442) 2,183 476 — (20) (20) — 1,727 125 176 301 383 13 $ $ 1,002 79 19 167 (28) 20 (14) 79 (10) (3) (8) 164 (59) (33) (39) 2,170 (2,411) — (31) (256) 260 (207) 207 3 (2,435) (472) (6) (157) (580) 1,527 68 — (29) (17) — 334 69 107 176 367 13 $ $ The accompanying notes are an integral part of these consolidated financial statements. 88 AMEREN CORPORATION CONSOLIDATED STATEMENT OF SHAREHOLDERS’ EQUITY (In millions) Common Stock: Beginning of year Settlement of forward sale agreement through common shares issuance $ Common stock, end of year $ 3 — 3 $ 2 1 3 2 — 2 2021 December 31, 2020 2019 Other Paid-in Capital: Beginning of year Settlement of forward sale agreement through common shares issuance Shares issued under the ATM program Shares issued under the DRPlus and 401(k) plan Stock-based compensation activity Other paid-in capital, end of year Retained Earnings: Beginning of year Net income attributable to Ameren common shareholders Dividends on common stock Retained earnings, end of year Accumulated Other Comprehensive Income (Loss): Deferred retirement benefit costs, beginning of year Change in deferred retirement benefit costs Deferred retirement benefit costs, end of year Total accumulated other comprehensive gain (loss), end of year Total Shareholders’ Equity Noncontrolling Interests: Beginning of year Net income attributable to noncontrolling interest holders Dividends paid to noncontrolling interest holders Redemptions of Ameren Illinois preferred stock Noncontrolling interests, end of year 6,179 113 148 47 15 6,502 2,757 990 (565) 3,182 (1) 14 13 13 5,694 424 — 51 10 6,179 2,380 871 (494) 2,757 (17) 16 (1) (1) 5,627 — — 68 (1) 5,694 2,024 828 (472) 2,380 (22) 5 (17) (17) $ 9,700 $ 8,938 $ 8,059 142 5 (5) (13) 129 142 6 (6) — 142 142 6 (6) — 142 Total Equity $ 9,829 $ 9,080 $ 8,201 Common stock shares outstanding at beginning of year Shares issued under forward sale agreement Shares issued under the ATM program Shares issued under the DRPlus and 401(k) plan Shares issued for stock-based compensation Common stock shares outstanding at end of year 253.3 1.6 1.8 0.5 0.5 257.7 246.2 5.9 — 0.7 0.5 253.3 244.5 — — 0.9 0.8 246.2 Dividends per common share $ 2.20 $ 2.00 $ 1.92 The accompanying notes are an integral part of these consolidated financial statements. 89 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF INCOME (In millions) $ Operating Revenues: Electric Natural gas Total operating revenues Operating Expenses: Fuel Purchased power Natural gas purchased for resale Other operations and maintenance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income, Net Interest Charges Income Before Income Taxes Income Taxes Net Income Preferred Stock Dividends Net Income Attributable to Ameren Common Shareholders $ Year Ended December 31, 2020 2021 2019 3,212 141 3,353 581 227 60 948 632 343 2,791 562 99 137 524 3 521 3 518 $ $ 2,984 125 3,109 490 171 43 886 604 328 2,522 587 76 190 473 34 439 3 436 $ $ 3,109 134 3,243 535 193 53 960 556 329 2,626 617 58 178 497 68 429 3 426 The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 90 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) BALANCE SHEET (In millions, except per share amounts) Current Assets: ASSETS Cash and cash equivalents Advances to money pool Accounts receivable – trade (less allowance for doubtful accounts of $13 and $16, respectively) Accounts receivable – affiliates Unbilled revenue Miscellaneous accounts receivable Inventories Current regulatory assets Current collateral assets Other current assets Total current assets Property, Plant, and Equipment, Net Investments and Other Assets: Nuclear decommissioning trust fund Regulatory assets Pension and other postretirement benefits Other assets Total investments and other assets TOTAL ASSETS LIABILITIES AND SHAREHOLDERS’ EQUITY Current Liabilities: Current maturities of long-term debt Short-term debt Accounts and wages payable Accounts payable – affiliates Taxes accrued Interest accrued Current asset retirement obligations Other current liabilities Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes and investment tax credits, net Regulatory liabilities Asset retirement obligations Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 9, 13, and 14) Shareholders’ Equity: Common stock, $5 par value, 150.0 shares authorized – 102.1 shares outstanding Other paid-in capital, principally premium on common stock Preferred stock Retained earnings Total shareholders’ equity TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY $ $ $ December 31, 2021 2020 $ $ $ — — 190 44 142 71 419 127 66 76 1,135 15,296 1,159 523 208 401 2,291 18,722 55 165 631 46 34 60 7 219 1,217 5,564 1,852 3,354 753 71 6,030 136 139 166 57 133 36 386 60 11 68 1,192 13,879 982 347 60 323 1,712 16,783 8 — 501 46 42 53 60 123 833 5,096 1,742 3,110 691 101 5,644 511 2,725 80 2,595 5,911 18,722 $ 511 2,518 80 2,101 5,210 16,783 $ The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 91 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF CASH FLOWS (In millions) Year Ended December 31, 2020 2021 2019 $ 521 $ 439 $ 429 Cash Flows From Operating Activities: Net income Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization Amortization of nuclear fuel Amortization of debt issuance costs and premium/discounts Deferred income taxes and investment tax credits, net Allowance for equity funds used during construction Other Changes in assets and liabilities: Receivables Inventories Accounts and wages payable Taxes accrued Regulatory assets and liabilities Assets, other Liabilities, other Pension and other postretirement benefits Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Wind generation expenditures Nuclear fuel expenditures Purchases of securities – nuclear decommissioning trust fund Sales and maturities of securities – nuclear decommissioning trust fund Purchase of bonds Proceeds from sale of remarketed bonds Money pool advances, net Other Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends on preferred stock Short-term debt, net Maturities of long-term debt Issuances of long-term debt Debt issuance costs Capital contribution from parent Net cash provided by financing activities Net change in cash, cash equivalents, and restricted cash Cash, cash equivalents, and restricted cash at beginning of year Cash, cash equivalents, and restricted cash at end of year Cash Paid During the Year: Interest (net of $10, $10, and $12 capitalized, respectively) Income taxes, net $ $ 704 58 6 3 (26) 19 (60) (32) 28 (27) (207) (27) (29) (2) 929 (1,490) (525) (44) (452) 439 — — 139 11 (1,922) (24) (3) 165 (8) 524 (5) 207 856 (137) 145 8 205 19 $ $ 613 68 6 17 (19) 22 (8) (11) 26 9 (166) (2) (80) (3) 911 (1,102) (564) (66) (224) 183 — — (139) 8 (1,904) (66) (3) (234) (92) 1,012 (9) 491 1,099 106 39 145 190 25 $ $ 564 79 5 (19) (19) 13 75 (13) 16 (15) 17 (28) (32) (5) 1,067 (1,076) — (31) (256) 260 (207) 207 — 8 (1,095) (430) (3) 179 (580) 778 (9) 124 59 31 8 39 190 101 The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 92 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF SHAREHOLDERS’ EQUITY (In millions) Common Stock Other Paid-in Capital: Beginning of year Capital contribution from parent Other paid-in capital, end of year Preferred Stock Retained Earnings: Beginning of year Net income Dividends on common stock Dividends on preferred stock Retained earnings, end of year 2021 December 31, 2020 2019 $ 511 $ 511 $ 511 2,518 207 2,725 80 2,101 521 (24) (3) 2,595 2,027 491 2,518 80 1,731 439 (66) (3) 2,101 1,903 124 2,027 80 1,735 429 (430) (3) 1,731 Total Shareholders’ Equity $ 5,911 $ 5,210 $ 4,349 The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 93 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF INCOME (In millions) $ Operating Revenues: Electric Natural gas Total operating revenues Operating Expenses: Purchased power Natural gas purchased for resale Other operations and maintenance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income, Net Interest Charges Income Before Income Taxes Income Taxes Net Income Preferred Stock Dividends Net Income Attributable to Ameren Common Shareholders $ Year Ended December 31, 2020 2019 2021 1,938 957 2,895 400 382 820 472 153 2,227 668 66 164 570 143 427 2 425 $ $ 1,775 760 2,535 355 229 775 434 140 1,933 602 59 155 506 124 382 3 379 $ $ 1,730 797 2,527 368 278 782 406 143 1,977 550 53 147 456 110 346 3 343 The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements. 94 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) BALANCE SHEET (In millions) Current Assets: ASSETS Cash and cash equivalents Accounts receivable – trade (less allowance for doubtful accounts of $16 and $34, respectively) Accounts receivable – affiliates Unbilled revenue Miscellaneous accounts receivable Inventories Current regulatory assets Other current assets Total current assets Property, Plant, and Equipment, Net Investments and Other Assets: Goodwill Regulatory assets Pension and other postretirement benefits Other assets Total investments and other assets TOTAL ASSETS LIABILITIES AND SHAREHOLDERS’ EQUITY Current Liabilities: Current maturities of long-term debt Short-term debt Borrowings from money pool Accounts and wages payable Accounts payable – affiliates Customer deposits Current regulatory liabilities Other current liabilities Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes and investment tax credits, net Regulatory liabilities Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 13, and 14) Shareholders’ Equity: Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding Other paid-in capital Preferred stock Retained earnings Total shareholders’ equity TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY $ $ $ December 31, 2021 2020 $ $ $ — 228 24 159 1 173 180 58 823 12,223 411 752 427 399 1,989 15,035 400 103 — 361 64 52 54 199 1,233 3,992 1,558 2,374 238 4,170 — 234 64 136 12 135 37 29 647 11,201 411 742 280 254 1,687 13,535 — — 19 363 51 74 88 221 816 3,946 1,367 2,063 377 3,807 — 2,914 49 2,677 5,640 15,035 $ — 2,652 62 2,252 4,966 13,535 $ The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements. 95 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF CASH FLOWS (In millions) Cash Flows From Operating Activities: Net income Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization Amortization of debt issuance costs and premium/discounts Deferred income taxes and investment tax credits, net Allowance for equity funds used during construction Other Changes in assets and liabilities: Receivables Inventories Accounts and wages payable Taxes accrued Regulatory assets and liabilities Assets, other Liabilities, other Pension and other postretirement benefits Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Other Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends on preferred stock Short-term debt, net Money pool borrowings, net Redemption of preferred stock Issuances of long-term debt Debt issuance costs Capital contribution from parent Other Net cash provided by financing activities Net change in cash, cash equivalents, and restricted cash Cash, cash equivalents, and restricted cash at beginning of year Cash, cash equivalents, and restricted cash at end of year Cash Paid During the Year: Interest (net of $7, $6, and $8 capitalized, respectively) Income taxes, net Year Ended December 31, 2020 2019 2021 $ 427 $ 382 $ 346 471 13 165 (17) 10 (17) (40) 2 22 (222) (75) (45) (32) 662 434 12 118 (13) 21 (28) (15) 15 (23) (72) (76) (46) (30) 679 405 12 80 (9) 16 11 2 (19) 21 155 (23) (5) (30) 962 (1,432) (5) (1,437) (1,447) 3 (1,444) (1,208) 3 (1,205) — (2) 103 (19) (13) 449 (6) 262 (13) 761 (14) 147 133 148 (41) $ $ (9) (3) (53) 19 — 373 (4) 464 — 787 22 125 147 137 41 $ $ — (3) (19) — — 299 (4) 15 — 288 45 80 125 127 4 $ $ The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements. 96 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF SHAREHOLDERS’ EQUITY (In millions) 2021 December 31, 2020 2019 $ — $ — $ — 2,652 262 2,914 62 (13) 49 2,252 427 — (2) 2,677 2,188 464 2,652 62 — 62 1,882 382 (9) (3) 2,252 2,173 15 2,188 62 — 62 1,539 346 — (3) 1,882 Common Stock Other Paid-in Capital: Beginning of year Capital contribution from parent Other paid-in capital, end of year Preferred Stock: Beginning of year Redemptions of preferred stock Preferred stock, end of year Retained Earnings: Beginning of year Net income Dividends on common stock Dividends on preferred stock Retained earnings, end of year Total Shareholders’ Equity $ 5,640 $ 4,966 $ 4,132 The accompanying notes as they relate to Ameren Illinois are an integral part of these financial statements. 97 AMEREN CORPORATION (Consolidated) UNION ELECTRIC COMPANY (d/b/a Ameren Missouri) AMEREN ILLINOIS COMPANY (d/b/a Ameren Illinois) COMBINED NOTES TO FINANCIAL STATEMENTS DECEMBER 31, 2021 NOTE 1 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES General Ameren, headquartered in St. Louis, Missouri, is a public utility holding company whose primary assets are its equity interests in its subsidiaries. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. Ameren also has other subsidiaries that conduct other activities, such as providing shared services. • • • Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business and a rate-regulated natural gas distribution business in Missouri. Ameren Missouri was incorporated in Missouri in 1922 and is successor to a number of companies, the oldest of which was organized in 1881. It is the largest electric utility in the state of Missouri. It supplies electric and natural gas service to a 24,000-square-mile area in central and eastern Missouri, which includes the Greater St. Louis area. Ameren Missouri supplies electric service to 1.2 million customers and natural gas service to 0.1 million customers. Ameren Illinois Company, doing business as Ameren Illinois, operates rate-regulated electric transmission, electric distribution, and natural gas distribution businesses in Illinois. Ameren Illinois was incorporated in Illinois in 1923 and is the successor to a number of companies, the oldest of which was organized in 1902. Ameren Illinois supplies electric and natural gas utility service to a 43,700 square mile area in central and southern Illinois. Ameren Illinois supplies electric service to 1.2 million customers and natural gas service to 0.8 million customers. Ameren Transmission Company of Illinois, doing business as ATXI, operates a FERC rate-regulated electric transmission business in the MISO. ATXI was incorporated in Illinois in 2006. In December 2020, ATXI completed construction of the ninth and final line segment of the Illinois Rivers transmission line, a MISO-approved electric transmission line. ATXI also operates the Spoon River and Mark Twain transmission lines, which were placed in service in February 2018 and December 2019, respectively. 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 2021, compared to 2020, and total sales volume levels were more comparable to pre-pandemic levels, there has been a shift in sales volumes by customer class, with an increase in residential sales, and a decrease in commercial and industrial sales. The continued effect of the 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 but not limited to impacts on our liquidity; demand for residential, commercial, and industrial electric and natural gas services; changes in deferred payment arrangements for customers; bad debt expense; supply chain operations; the availability of our employees and contractors; counterparty credit; capital construction; infrastructure operations and maintenance; and pension valuations. While the revenues from Ameren Illinois’ electric distribution business, residential and small nonresidential customers of Ameren Illinois’ natural gas distribution business, and Ameren Illinois’ and ATXI’s 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. 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. Our customers’ payment for our services has been impacted by the COVID-19 pandemic, resulting in a decrease to cash from operations. For information regarding Ameren Illinois’ suspension and subsequent reinstatement of customer disconnections and late fee charges for nonpayment and Ameren Missouri’s accounting authority orders related to the COVID-19 pandemic, see Note 2 – Rate and Regulatory Matters below. Ameren’s financial statements are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. All intercompany transactions have been eliminated, except as disclosed in Note 13 – Related-party Transactions. Ameren Missouri and Ameren Illinois have 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 98 liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the reported periods. Actual results could differ from those estimates. Regulation Our customer rates are regulated by the MoPSC, the ICC, and the FERC. We defer certain costs as assets pursuant to actions of rate regulators or because of expectations that we will be able to recover such costs in future rates charged to customers. We also defer certain amounts as liabilities pursuant to actions of rate regulators or based on the expectation that such amounts will be refunded to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. See Note 2 – Rate and Regulatory Matters for additional information on our regulatory frameworks, regulatory recovery mechanisms, and regulatory assets and liabilities recorded at December 31, 2021 and 2020. We continually assess the recoverability of our respective regulatory assets. Regulatory assets are charged to earnings when it is no longer probable that such amounts will be recovered through future revenues. To the extent that reductions in customers’ rates or refunds to customers related to regulatory liabilities are no longer probable, the amounts are credited to earnings. Cash, Cash Equivalents, and Restricted Cash Cash and cash equivalents include short-term, highly liquid investments purchased with an original maturity of three months or less. Cash and cash equivalents subject to legal or contractual restrictions and not readily available for use for general corporate purposes are classified as restricted cash. See Note 15 – Supplemental Information for a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets and the statements of cash flows. Allowance for Doubtful Accounts Receivable The allowance for doubtful accounts represents our estimate of existing accounts receivable that will ultimately be uncollectible. The allowance is calculated by applying estimated loss factors to various classes of outstanding receivables, including unbilled revenue. The loss factors used to estimate uncollectible accounts are based upon both historical collections experience and management’s estimate of future collections success given the existing and anticipated future collections environment. Ameren Illinois has bad debt riders that adjust rates for net write-offs of customer accounts receivable above or below those being collected in rates. In 2020, the rider for electric distribution allowed for recovery of bad debt expense recognized under GAAP. Inventories Inventories are recorded at the lower of weighted-average cost or net realizable value. Inventories are capitalized when purchased and then expensed as consumed or capitalized as property, plant, and equipment when installed, as appropriate. See Note 15 – Supplemental Information for the components of inventories. Property, Plant, and Equipment, Net We capitalize the cost of additions to, and betterments of, units of property, plant, and equipment. The cost includes labor, material, applicable taxes, and overhead. An allowance for funds used during construction, as discussed below, is also capitalized as a cost of our rate-regulated assets. Maintenance expenditures are expensed as incurred. Beginning in 2020, maintenance expenses related to scheduled Callaway nuclear refueling and maintenance outages, which were previously expensed as incurred, are deferred and amortized over the number of expected months until the completion of the next refueling outage, which historically has been approximately 18 months. When units of depreciable property are retired, the original costs, and the associated removal cost, net of salvage, are charged to accumulated depreciation. If environmental expenditures are related to assets currently in use, as in the case of the installation of pollution control equipment, the cost is capitalized and depreciated over the expected life of the asset. See Asset Retirement Obligations section below and Note 3 – Property, Plant, and Equipment, Net for additional information. Ameren Missouri’s cost of nuclear fuel is capitalized as a part of “Property, Plant, and Equipment, Net” on the balance sheet and then amortized to “Operating Expenses – Fuel” in the statement of income on a unit-of-production basis. Plant to be Abandoned, Net When it becomes probable an asset will be retired significantly in advance of its previously expected useful life and in the near term, the Ameren Companies must assess the probability of full recovery of the remaining net book value of the asset to be abandoned. We recognize a loss on abandonment when it becomes probable that all or part of the cost of an asset, including a return at the applicable WACC, will be disallowed from recovery either through customer rates or through the issuance of securitized utility tariff bonds and such amount is reasonably estimable. An abandonment loss, if any, would equal the difference between the remaining net book value of the asset and the present value of the expected future cash flows. If the asset is still in service, the net book value is classified as plant to be abandoned, net, 99 within “Property, Plant, and Equipment, Net” on the balance sheet. The net book value will be classified as a regulatory asset on the balance sheet when the asset is no longer in service or as required by a rate order. In relation to the NSR and Clean Air Act litigation discussed in Note 14 – Commitments and Contingencies, in December 2021, Ameren Missouri filed a motion with the United States District Court for the Eastern District of Missouri to modify a previously issued remedy order to allow the retirement of the Rush Island Energy Center in lieu of installing a flue gas desulfurization system. As of December 31, 2021, Ameren and Ameren Missouri determined that the Rush Island Energy Center met the criteria to be considered probable of abandonment and have classified its remaining net book value as plant to be abandoned, net, within “Property, Plant, and Equipment, Net” on Ameren’s and Ameren Missouri’s balance sheets. See Note 3 – Property, Plant, and Equipment, Net for our plant to be abandoned balance as of December 31, 2021. Ameren Missouri is currently allowed a full recovery of and a full return on its investment in Rush Island Energy Center and has concluded that no abandonment loss was required as of December 31, 2021. 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. Depreciation Depreciation is provided over the estimated lives of the various classes of depreciable property by applying composite rates on a straight-line basis to the cost basis of such property. The composite rates include a provision for the estimated removal cost of property, plant, and equipment retired from service, net of salvage. The provision for depreciation for the Ameren Companies in 2021, 2020, and 2019 ranged from 3% to 4% of the average depreciable cost. See Note 3 – Property, Plant, and Equipment, Net for additional information on estimated depreciable lives. Allowance for Funds Used During Construction As a part of “Property, Plant, and Equipment, Net” on the balance sheet, we capitalize allowance for funds used during construction, which is the cost of borrowed funds and the cost of equity funds (preferred and common shareholders’ equity) applicable to eligible rate- regulated construction work in progress, in accordance with the utility industry’s accounting practice and GAAP. The amount of allowance for funds used during construction is calculated using a FERC-prescribed formula based on a rate, which incorporates the average cost of short- term debt, the average cost of long-term debt, and the cost of equity funds. The portion attributable to borrowed funds is recorded as a reduction of “Interest Charges” on the statements of income. The portion attributable to equity funds is recorded within “Other Income, Net” on the statements of income. This accounting practice offsets the effect on earnings of the cost of financing during construction. See Note 15 – Supplemental Information for the amount of allowance for funds used during construction capitalized and the average rate applied to eligible construction work in progress. Allowance for funds used during construction does not represent a current source of cash funds. Under accepted ratemaking practice, cash recovery of allowance for funds used during construction and other construction costs occurs when completed projects are placed in service and reflected in customer rates. Goodwill Goodwill represents the excess of the purchase price of an acquisition over the fair value of the net assets acquired. Ameren and Ameren Illinois had goodwill of $411 million at December 31, 2021 and 2020. Ameren has four reporting units: Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Transmission. Ameren Illinois has three reporting units: Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Illinois Transmission. Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Illinois Transmission had goodwill of $238 million, $80 million, and $93 million, respectively, at December 31, 2021 and 2020. The Ameren Transmission reporting unit had the same $93 million of goodwill as the Ameren Illinois Transmission reporting unit at December 31, 2021 and 2020. Ameren and Ameren Illinois evaluate goodwill for impairment in each of their reporting units as of October 31 each year, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of their reporting units below their carrying amounts. To determine whether the fair value of a reporting unit is more likely than not greater than its carrying amount, Ameren and Ameren Illinois elect to perform either a qualitative assessment or to bypass the qualitative assessment and perform a quantitative test. Ameren and Ameren Illinois elected to perform a qualitative assessment for their annual goodwill impairment test conducted as of October 31, 2021. As part of this qualitative assessment, Ameren and Ameren Illinois evaluated, among other things, macroeconomic conditions, industry and market considerations such as observable industry market multiples, regulatory frameworks, cost factors, overall financial performance, and entity-specific events. The results of Ameren’s and Ameren Illinois’ qualitative assessment indicated that it was 100 more likely than not that the fair value of each reporting unit exceeded its carrying value as of October 31, 2021, resulting in no impairment of Ameren’s or Ameren Illinois’ goodwill. Impairment of Long-lived Assets We evaluate long-lived assets classified as held and used for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Whether an impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets to the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, we recognize an impairment charge equal to the amount by which the carrying value exceeds the estimated fair value of the assets. In the period in which we determine that an asset meets held for sale criteria, we record an impairment charge to the extent the book value exceeds its estimated fair value less cost to sell. We did not identify any events or changes in circumstances that indicated that the carrying value of long-lived assets may not be recoverable in 2021, 2020 or 2019. Variable Interest Entities As of December 31, 2021 and 2020, Ameren had unconsolidated variable interests as a limited partner in various equity method investments, primarily to advance clean and resilient energy technologies, totaling $56 million and $37 million, respectively, included in “Other assets” on Ameren’s consolidated balance sheet. Any earnings or losses related to these investments are included in “Other Income, Net” on Ameren’s consolidated statement of income and comprehensive income. Ameren is not the primary beneficiary of these investments because it does not have the power to direct matters that most significantly affect the activities of these variable interest entities. As of December 31, 2021, the maximum exposure to loss related to these variable interest entities is limited to the investment in these partnerships of $56 million plus associated outstanding funding commitments of $28 million. Environmental Costs Liabilities for environmental costs are recorded on an undiscounted basis when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated. Costs are expensed or deferred as a regulatory asset when it is expected that the costs will be recovered from customers in future rates. See Note 14 – Commitments and Contingencies for additional information on liabilities for environmental costs. Asset Retirement Obligations and Removal Costs We record the estimated fair value of legal obligations associated with the retirement of tangible long-lived assets in the period in which the liabilities are incurred and capitalize a corresponding amount as part of the book value of the related long-lived asset. In subsequent periods, we adjust AROs for accretion and changes in the estimated fair values of the obligations, with a corresponding increase or decrease in the asset book value for the fair value changes. Asset book values, reflected within “Property, Plant, and Equipment, Net” on the balance sheet, are depreciated over the remaining useful life of the related asset. Due to regulatory recovery, that depreciation is deferred as a regulatory balance. The depreciation of the asset book values at Ameren Missouri was $14 million, $28 million, and $18 million for the years ended December 31, 2021, 2020, and 2019, respectively, which was deferred as a reduction to the net regulatory liability. The net regulatory liability also reflects a deferral for the nuclear decommissioning trust fund balance for the Callaway Energy Center. The depreciation deferred to the regulatory asset at Ameren Illinois was immaterial in each respective period. Uncertainties as to the probability, timing, or amount of cash expenditures associated with AROs affect our estimates of fair value. Ameren and Ameren Missouri have recorded AROs for retirement costs associated with decommissioning of Ameren Missouri’s Callaway and wind renewable energy centers, certain Ameren Missouri solar energy centers, CCR facilities, and river structures at certain energy centers used for unloading coal and circulating water systems. Additionally, Ameren, Ameren Missouri, and Ameren Illinois have recorded AROs for retirement costs associated with asbestos removal and the disposal of certain transformers. See Note 15 – Supplemental Information for a reconciliation of the beginning and ending carrying amounts of AROs. Estimated funds collected from customers to pay for the future removal cost of property, plant, and equipment retired from service, net of salvage, represent a cost of removal regulatory liability. See the cost of removal regulatory liability balance in Note 2 – Rate and Regulatory Matters. 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 December 31, 2021, the cash surrender value of company-owned life insurance at Ameren and Ameren Illinois was $278 million (December 31, 2020 – $272 million) and $117 million (December 31, 2020 – $115 million), respectively, while total borrowings against the policies were $109 million (December 31, 2020 – $107 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 101 sheets. The net cash surrender value of Ameren’s company-owned life insurance is affected by the investment performance of a separate account in which Ameren holds a beneficial interest. Operating Revenues We record revenues from contracts with customers for various electric and natural gas services, which primarily consist of retail distribution, electric transmission, and off-system arrangements. When more than one performance obligation exists in a contract, the consideration under the contract is allocated to the performance obligations based on the relative standalone selling price. Electric and natural gas retail distribution revenues are earned when the commodity is delivered to our customers. We accrue an estimate of electric and natural gas retail distribution revenues for service provided but unbilled at the end of each accounting period. Electric transmission revenues are earned as electric transmission services are provided. Off-system revenues are primarily comprised of MISO revenues and wholesale bilateral revenues. MISO revenues include the sale of electricity, capacity, and ancillary services. Wholesale bilateral revenues include the sale of electricity and capacity. MISO-related electricity and wholesale bilateral electricity revenues are earned as electricity is delivered. Capacity and ancillary service revenues are earned as services are provided. Retail distribution, electric transmission, and off-system revenues, including the underlying components described above, represent a series of goods or services that are substantially the same and have the same pattern of transfer over time to our customers. Revenues from contracts with customers are equal to the amounts billed and our estimate of electric and natural gas retail distribution services provided but unbilled at the end of each accounting period. Customers are billed at least monthly, and payments are due less than one month after goods and/or services are provided. See Note 16 – Segment Information for disaggregated revenue information. For certain regulatory recovery mechanisms that are alternative revenue programs rather than revenues from contracts with customers, we recognize revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected from customers within two years from the end of the year. Our alternative revenue programs include revenue requirement reconciliations, the MEEIA, the VBA, and the WNAR. These revenues are subsequently recognized as revenues from contracts with customers when billed, with an offset to alternative revenue program revenues. As of December 31, 2021 and 2020, our remaining performance obligations 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. Accounting for MISO Transactions MISO-related purchase and sale transactions are recorded by Ameren, Ameren Missouri, and Ameren Illinois using settlement information provided by the MISO. Ameren Missouri records these purchase and sale transactions on a net hourly position. Ameren Missouri records net purchases in a single hour in “Operating Expenses – Purchased power” and net sales in a single hour in “Operating Revenues – Electric” in its statement of income. Ameren Illinois records net purchases in “Operating Expenses – Purchased power” in its statement of income to reflect all of its MISO transactions relating to the procurement of power for its customers. On occasion, Ameren Missouri’s and Ameren Illinois’ prior-period transactions will be resettled outside the routine settlement process because of a change in the MISO’s tariff or a material interpretation thereof. In these cases, Ameren Missouri and Ameren Illinois recognize revenues and expenses associated with resettlements once the resettlement is probable and the resettlement amount can be estimated. There were no material MISO resettlements in 2021, 2020, or 2019. Stock-based Compensation Stock-based compensation cost is measured at the grant date based on the fair value of the award, net of an assumed forfeiture rate. Ameren recognizes as compensation expense the estimated fair value of stock-based compensation on a straight-line basis over the requisite vesting period. To the extent that actual forfeitures differ from estimated forfeitures, such differences are accounted for as a cumulative adjustment to compensation expense and recorded in the period that estimates are revised. Compensation cost is ultimately recognized only for awards for which the requisite service was provided. See Note 11 – Stock-based Compensation for additional information. Unamortized Debt Discounts, Premiums, and Issuance Costs Long-term debt discounts, premiums, and issuance costs are amortized over the lives of the related issuances. Credit agreement fees are amortized over the term of the agreement. 102 Income Taxes Ameren uses an asset and liability approach for its financial accounting and reporting of income taxes. Deferred tax assets and liabilities are recognized for transactions that are treated differently for financial reporting and income tax return purposes. These deferred tax assets and liabilities are based on statutory tax rates. We expect that regulators will reduce future revenues for deferred tax liabilities that were initially recorded at rates in excess of the current statutory rate. Therefore, reductions in certain deferred tax liabilities that were recorded because of decreases in the statutory rate have been credited to a regulatory liability. A regulatory asset has been established to recognize the probable recovery through future customer rates of tax benefits related to the equity component of allowance for funds used during construction, as well as the effects of tax rate increases. To the extent deferred tax balances are included in rate base, the revaluation of deferred taxes is recorded as a regulatory asset or liability on the balance sheet and will be collected from, or refunded to, customers. For deferred tax balances not included in rate base, the revaluation of deferred taxes is recorded as an adjustment to income tax expense on the income statement. See Note 12 – Income Taxes for further information regarding the revaluation of deferred taxes related to Missouri state corporate income tax rate changes. Ameren Missouri, Ameren Illinois, and all the other Ameren subsidiary companies are parties to a tax allocation agreement with Ameren (parent) that provides for the allocation of consolidated tax liabilities. The tax allocation agreement specifies that each party be allocated an amount of tax using a stand-alone calculation, which is similar to what would be owed or refunded had the party been separately subject to tax without considering the impact of consolidation. Any net benefit attributable to Ameren (parent) is reallocated to the other parties. This reallocation is treated as a capital contribution to the party receiving the benefit. See Note 13 – Related-party Transactions for information regarding capital contributions under the tax allocation agreement. NOTE 2 – RATE AND REGULATORY MATTERS Below is a summary of our regulatory frameworks and significant regulatory proceedings and related lawsuits. We are unable to predict the ultimate outcome of these matters, the timing of final decisions of the various agencies and courts, or the effect on our results of operations, financial position, or liquidity. Regulatory Frameworks The following table presents the regulatory frameworks and significant regulatory recovery mechanisms for each of Ameren’s rate- regulated businesses, which are discussed in more detail below: Regulatory framework Ameren Missouri • Historical test year ratemaking • Natural gas revenues for residential customers adjusted for sales volume deviations resulting from weather through the WNAR Regulatory mechanisms • PISA Riders: • RESRAM • FAC • MEEIA • PGA • WNAR Trackers: • Pension and postretirement benefit costs • Certain excess deferred income taxes • Renewable energy standard costs Ameren Illinois’ electric distribution business Ameren Illinois’ natural gas delivery service business Ameren Illinois’ and ATXI’s electric transmission business • Future test year ratemaking • Revenues for residential and small nonresidential customers decoupled from sales volumes through the VBA • Formula ratemaking • Initial rates based on future test year • Revenues decoupled from sales volumes • Revenue requirement reconciliation adjustment Riders: • QIP • PGA • VBA • Energy-efficiency program costs • Certain environmental costs • Bad debt write-offs • Invested capital taxes • Performance-based formula ratemaking • Initial rates based on historical test year and expected net plant additions for the year before rates become effective • Revenues decoupled from sales volumes • Electric distribution service and energy-efficiency revenue requirement reconciliation adjustments Riders: • Power procurement • Transmission services • Renewable energy credit compliance • Zero emission credits • Certain environmental costs • Bad debt write-offs • Costs of certain asbestos- related claims Missouri The MoPSC regulates rates and other matters for Ameren Missouri’s electric service and natural gas distribution businesses. The rates Ameren Missouri charges customers for these services are established in a traditional regulatory rate review, which takes up to 11 months to complete, based on a historical test year and the revenue requirement established in the review. 103 Ameren Missouri has recovery mechanisms, including the RESRAM, FAC, MEEIA, PGA, and WNAR, that allow customer rates to be adjusted without a traditional regulatory rate review. These riders, along with the PISA, each described in more detail below, partially mitigate the effects of regulatory lag. Ameren Missouri also employs other recovery mechanisms, including a pension and postretirement benefit cost tracker, an uncertain income tax position tracker, a tracker on certain excess deferred income taxes, and a renewable energy standard cost tracker. Each of these trackers allows Ameren Missouri to defer the difference between actual costs incurred and costs included in customer rates as a regulatory asset or regulatory liability, with the difference expected to be reflected in base rates in a subsequent MoPSC rate order. Ameren Missouri’s cost recovery under any of its recovery mechanisms is subject to MoPSC prudence reviews. 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 15% of depreciation expense not recovered under the PISA, and earn a return at the applicable WACC for investments in renewable generation plant placed in service to comply with Missouri’s renewable energy standard. The RESRAM deferrals are a regulatory asset until they are included in customer rates and collected in a subsequent period. Those investments not eligible for recovery under the PISA and the remaining 15% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. 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. Under Missouri law, as a result of the PISA election, additional provisions apply to Ameren Missouri. These provisions include limiting Ameren Missouri’s rate increases to a 2.85% compound annual growth rate in the average overall customer rate per kilowatthour, based on the electric rates that became effective in April 2017, less half of the annual savings from the TCJA that was passed on to customers as approved in a July 2018 MoPSC order. If rate changes from the FAC or the RESRAM riders would cause rates to temporarily exceed the 2.85% rate cap, the overage would be deferred for future recovery in the next regulatory rate review; however, rates established in such regulatory rate review would be subject to the rate cap. Any deferred overages approved for recovery would be recovered in a manner consistent with costs recovered under the PISA. Excluding customer rates under the MEEIA rider, which are not subject to the rate cap, Ameren Missouri would incur a penalty equal to the amount of deferred overage that would cause customer rates to exceed the 2.85% rate cap. Ameren Missouri did not incur a penalty related to the rate cap in 2021. Both the rate increase limitation and the PISA are effective through December 2023. Missouri law provides for the ability to use the PISA, if Ameren Missouri requests and receives MoPSC approval for extension, through December 2028. The RESRAM permits Ameren Missouri to recover or refund, through customer rates, the difference between the cost of compliance, net of renewable tax credits, with Missouri’s renewable energy standard and the amount set in base rates. Effective February 28, 2022, all off- system sales from the High Prairie Renewable and Atchison Renewable energy centers will be included in the RESRAM. Previously, 95% of these sales were included in the FAC and 5% were included in the RESRAM. Customer rates are adjusted for the RESRAM on an annual basis without a traditional regulatory rate review, subject to MoPSC prudence reviews. The difference between actual compliance costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to customers in a subsequent period. RESRAM regulatory assets earn carrying costs at short-term interest rates. The RESRAM permits Ameren Missouri to recover investments in wind generation and other renewables related to compliance with Missouri’s renewable energy standard, and earn a return at the applicable WACC on those investments not already provided for in customer rates or any other recovery mechanism, such as the renewable energy standard cost tracker. The renewable energy standard cost tracker allows Ameren Missouri to defer differences between actual costs primarily associated with the Maryland Heights Energy Center and renewable energy credits obtained through a 102-MW power purchase agreement with a wind farm operator, which expires in 2024, and those costs included in customer rates. The FAC permits Ameren Missouri to recover or refund, through customer rates, 95% of the variance in net energy costs from the amount set in base rates without a traditional regulatory rate review, subject to MoPSC prudence reviews, with the remaining 5% of changes retained by Ameren Missouri. As such, Ameren Missouri’s results of operations are affected by the 5% not recovered or refunded under the FAC. The 95% variance in net energy costs in a given period is deferred as a regulatory asset or liability, and either billed or refunded to customers in a subsequent period. FAC regulatory assets earn carrying costs at short-term interest rates. Ameren Missouri’s base rates for electric service are required to be reset at least every four years to allow for continued use of the FAC. The MEEIA permits Ameren Missouri to recover customer energy-efficiency program costs, the related lost electric margins, and any performance incentive through the MEEIA without a traditional regulatory rate review, subject to MoPSC prudence reviews. MEEIA assets earn carrying costs at short-term interest rates. Ameren Missouri is a member of the MISO, and its transmission rate is calculated in accordance with the MISO Open Access Transmission, Energy, and Operating Reserve Markets Tariff. The FERC regulates the rates charged and the terms and conditions for wholesale electric transmission service. The transmission rate update each June is based on Ameren Missouri’s actual historical cost from the prior calendar year. This rate is not directly charged to Missouri retail customers because, in Missouri, the revenue requirement used to set bundled retail base rates includes an amount for transmission-related costs and revenues. 104 The PGA allows Ameren Missouri to recover costs of natural gas purchased on behalf of its customers without a traditional regulatory rate review, subject to MoPSC prudence reviews. These pass-through purchased gas costs do not affect Ameren Missouri’s natural gas margins, as any change in costs is offset by a corresponding change in revenues. The difference between actual natural gas costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to customers in a subsequent period. PGA regulatory assets earn carrying costs at short-term interest rates. The WNAR will allow Ameren Missouri to adjust natural gas delivery service rates charged to residential customers without a traditional regulatory rate review, subject to MoPSC prudence reviews, when deviations from normal weather conditions cause natural gas revenues to vary from the related revenue requirement approved by the MoPSC in the previous regulatory rate review. The impact of deviations from normal weather on natural gas delivery service revenues billed to residential customers in a given period will be deferred as a regulatory asset or liability. WNAR regulatory assets will earn carrying costs at short-term interest rates. The deferred amount will either be billed or refunded to residential customers in a subsequent period. The WNAR was approved by the December 2021 MoPSC natural gas rate order discussed below, and will replace the DCA effective February 28, 2022. Illinois The ICC regulates rates and other matters for Ameren Illinois’ electric distribution service and natural gas distribution businesses. The rates Ameren Illinois charges customers for electric distribution service are calculated under a performance-based formula ratemaking framework pursuant to the IEIMA. Pursuant to the IETL and 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 requirements, and anticipates filing an MYRP by mid-January 2023, with rates effective beginning in 2024. By law, the decoupling 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. See below for additional information regarding the IETL, the MYRP, and the March 2021 ICC order. The rates Ameren Illinois charges customers for natural gas distribution service are established in a traditional regulatory rate review, which takes up to 11 months to complete, based on a future test year and the revenue requirement established in the review. Ameren Illinois’ election to use the electric distribution service performance-based formula ratemaking framework allowed by state law, described below, permits Ameren Illinois to adjust customer rates to recover the cost of electric distribution service on an annual basis. Ameren Illinois’ electric distribution service also has other cost recovery mechanisms in place that allow customer rates to be adjusted without a traditional regulatory rate review. Ameren Illinois’ electric distribution service business has riders for power procurement and transmission services incurred on behalf of its customers, renewable energy credit compliance, zero emission credits, and certain environmental costs, as well as bad debt write-offs and the costs of certain asbestos-related claims not recovered in base rates. These pass- through costs do not affect Ameren Illinois’ net income, as any change in costs is offset by a corresponding change in revenues. Ameren Illinois’ cost recovery under any of its recovery mechanisms is subject to ICC prudence reviews. 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. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is then collected from, or refunded to, customers within two years from the end of the year. In addition, Ameren Illinois’ electric customer energy-efficiency rider provides Ameren Illinois’ electric distribution service business with recovery of, and return on, energy-efficiency investments. Under formula ratemaking for both its electric distribution service and its electric energy-efficiency investments, the revenue requirements are based on recoverable costs, year-end rate base, and a year-end ratemaking capital structure, and earn a return at the applicable WACC. The ROE component of the applicable WACC is based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points and any performance-related basis point adjustments, described in more detail below. Therefore, Ameren Illinois’ annual ROE for its electric distribution business is directly correlated to the yields on such bonds. In addition, regulatory assets applicable to formula ratemaking for both electric distribution service and electric energy-efficiency investments earn a return at the applicable WACC. However, Ameren Illinois recognizes the cost of debt on these regulatory assets in revenue, instead of the applicable WACC, with the difference recognized in revenues when recovery of such regulatory assets is reflected in customer rates. Ameren Illinois’ electric distribution service business is also subject to performance standards. Failure to achieve the standards would result in a reduction in the company’s allowed ROE calculated under the formula ratemaking recovery mechanism. The performance standards applicable to electric distribution service under the IEIMA include improvements in service reliability to reduce both the frequency and duration of outages, a reduction in the number of estimated bills, a reduction of consumption from inactive meters, and a reduction in bad debt expense. The allowed ROE for electric distribution service may be decreased for penalties up to 38 basis points in 2022 and up to 10 basis points in 2023 if these performance standards are not met. The allowed ROE on energy-efficiency investments can be increased or decreased up to 200 basis points, depending on the achievement of annual energy savings goals. Any adjustments to the allowed ROE for energy-efficiency investments will depend on annual performance for a historical period relative to energy savings goals. In 2021, 2020, and 2019, there were no performance-related basis point adjustments that materially affected financial results. 105 Ameren Illinois’ natural gas distribution business has recovery mechanisms, including the QIP, PGA, and VBA, that allow customer rates to be adjusted without a traditional regulatory rate review. These riders, described in more detail below, mitigate the effects of regulatory lag. Ameren Illinois employs other riders for natural gas customer energy-efficiency program costs and certain environmental costs, as well as bad debt write-offs and invested capital taxes not recovered in base rates. Pass-through costs under the riders do not affect Ameren Illinois’ net income, as any change in costs is offset by a corresponding change in revenues. Ameren Illinois’ cost recovery under any of its recovery mechanisms is subject to ICC prudence reviews. The QIP provides Ameren Illinois with recovery of, and a return on, qualifying natural gas infrastructure investments that are placed in service between regulatory rate reviews. Infrastructure investments under the QIP earn a return at the applicable WACC. Eligible natural gas investments include projects to improve safety and reliability and modernization investments, such as smart meters. The deferrals are recorded as a regulatory asset, with recovery beginning two months after the qualifying natural gas plant is placed in service and continuing until such plant is included in base rates in a natural gas delivery service rate order. Ameren Illinois’ QIP is subject to a rate impact limitation of a cumulative 4% per year since the most recent delivery service rate order, with no single year exceeding 5.5%. If the rate impact limitation was met in a particular year, the amount of rate base causing the QIP rate to exceed the limitation would be exposed to regulatory lag until a year when that amount could be recovered under QIP or is added to rate base as a part of a regulatory rate review. Upon issuance of a natural gas delivery service rate order, QIP rate base is transferred to base rates and the QIP is reset to zero, which mitigates the risk that the QIP will exceed its statutory limitations in future years and ensures timely recovery of capital investments. Without legislative action, the QIP will expire after December 2023. The PGA allows Ameren Illinois to recover costs of natural gas purchased on behalf of its customers without a traditional regulatory rate review, subject to ICC prudence reviews. These pass-through purchased gas costs do not affect Ameren Illinois natural gas margins, as any change in costs is offset by a corresponding change in revenues. The difference between actual natural gas costs and costs billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is either billed or refunded to customers in a subsequent period. PGA regulatory assets earn carrying costs at short-term interest rates. The VBA ensures recoverability of the natural gas distribution service revenue requirement that is dependent on sales volumes for residential and small nonresidential customers. For these rate classes, the VBA allows Ameren Illinois to adjust natural gas distribution service rates without a traditional regulatory rate review when changes occur in sales volumes from those volumes approved by the ICC in a previous regulatory rate review. The difference between allowed sales revenues and amounts billed to customers in a given period is deferred as a regulatory asset or liability. The deferred amount is collected from, or refunded to, customers in a subsequent period. VBA regulatory assets for a given year that are not fully collected by the end of the following year begin earning carrying costs at short-term interest rates. Federal The FERC regulates rates and other matters for Ameren Illinois’ transmission business and ATXI, as well as for Ameren Missouri. See discussion above related to Ameren Missouri. Both Ameren Illinois and ATXI are members of the MISO, and their transmission rates are calculated in accordance with the MISO Open Access Transmission, Energy, and Operating Reserve Markets Tariff. Ameren Illinois and ATXI have received FERC approval to use a company-specific, forward-looking formula ratemaking framework in setting their transmission rates. These forward-looking rates are updated annually and become effective each January with forecasted information. The formula rate framework provides for an annual reconciliation of the electric transmission service revenue requirement, which reflects the actual recoverable costs incurred and the 13-month average rate base for a given year, with the revenue requirement in customer rates, including an allowed ROE. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance is collected from, or refunded to, customers within two years from the end of the year. FERC revenue requirement reconciliation adjustment regulatory assets earn carrying costs at each company’s short-term interest rates. In addition, the FERC has approved transmission rate incentives, including a 50 basis point incentive adder to the allowed base ROE for Ameren Illinois and ATXI for participation in an RTO. Proceedings and Updates Missouri December 2021 MoPSC Electric Rate Order In December 2021, the MoPSC issued an order in Ameren Missouri’s 2021 electric service regulatory rate review, approving nonunanimous stipulations and agreements. The order will result in an increase of $220 million to Ameren Missouri’s annual revenue requirement for electric retail service. The approved revenue requirement is based on a rate base of $10.2 billion, infrastructure investments as of September 30, 2021, and a change in the depreciable lives of the Sioux and Rush Island energy centers’ assets consistent with Ameren Missouri’s 2020 IRP. The order did not specify an ROE, but specified that Ameren Missouri’s September 30, 2021 capital structure, which was composed of 51.97% common equity, will be used in the PISA and RESRAM. The order provides for the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, certain excess deferred income taxes, and renewable 106 energy standard costs that the MoPSC previously authorized in earlier electric rate orders. The order also changed annualized depreciation, regulatory asset and liability amortization amounts, and the base level of expenses for trackers. On an annualized basis, these changes reflect approximate increases in depreciation and amortization of $140 million and other operating and maintenance expenses of $40 million. As a result of the order, all off-system sales resulting from the High Prairie Renewable and Atchison Renewable energy centers will be included in the RESRAM beginning February 28, 2022. Prior to this change, 95% of these sales were included in the FAC and 5% were included in the RESRAM. The order also establishes a five-year recovery period for $61 million of certain costs associated with the Meramec Energy Center, which is expected to be retired in 2022. The new rates, base level of expenses, and amortizations will become effective on February 28, 2022. MoPSC Staff Review of Planned Rush Island Energy Center Retirement In February 2022, the MoPSC issued an order directing the MoPSC staff to review Ameren Missouri’s planned accelerated retirement of the Rush Island Energy Center as a result of the NSR and Clean Air Act Litigation discussed in Note 14 – Commitments and Contingencies. The MoPSC staff’s review will include potential impacts on the reliability and cost of Ameren Missouri’s service to its customers, Ameren Missouri’s plans to mitigate the customer impacts of the accelerated retirement, and the prudence of Ameren Missouri’s actions and decisions with regard to the Rush Island Energy Center, among other things. The MoPSC staff is under no deadline to complete this review. Ameren Missouri is unable to predict the ultimate resolution of this matter; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. December 2021 MoPSC Natural Gas Rate Order In December 2021, the MoPSC issued an order in Ameren Missouri’s 2021 natural gas delivery service regulatory rate review, approving nonunanimous stipulations and agreements. The order will result in an increase of $5 million to Ameren Missouri’s annual revenue requirement for natural gas delivery service. The approved revenue requirement is based on a rate base of $313 million and infrastructure investments as of September 30, 2021. The order did not specify an ROE or a capital structure. The order provides for the continued use of the PGA and trackers for pension and postretirement benefits and certain excess deferred income taxes that the MoPSC previously authorized in earlier natural gas rate orders. The order also authorizes the use of the WNAR, which replaces the DCA and is discussed above. The new rates will become effective on February 28, 2022. Accounting Authority Orders Related to COVID-19 Pandemic Costs In March 2021, the MoPSC issued orders approving nonunanimous stipulation and agreements related to Ameren Missouri’s electric and natural gas service accounting authority order requests. The orders allowed Ameren Missouri to accumulate $9 million of certain costs incurred related to the COVID-19 pandemic, net of cost savings, as well as forgone customer late fee and reconnection fee revenues from March 2020 to March 2021. The accumulated costs and forgone customer late fee and reconnection fee revenues were approved for recovery in the MoPSC’s December 2021 electric and natural gas rate orders discussed above. In March 2021, Ameren Missouri deferred other operations and maintenance expenses of $5 million as a regulatory asset related to the accounting authority orders and will amortize the balance over a five-year period once new rates become effective on February 28, 2022. Ameren Missouri will recognize the remaining $4 million associated with forgone customer late fee and reconnection fee revenue when billed to customers over the five-year period beginning on February 28, 2022. MEEIA In September 2021, the MoPSC issued an order approving Ameren Missouri’s energy savings results for the second year of the MEEIA 2019 program. As a result of this order and MoPSC orders issued in September 2017, October 2018, January 2019, September 2019, and August 2020, and in accordance with revenue recognition guidance, Ameren Missouri recognized revenues of $9 million, $6 million, and $37 million in 2021, 2020, and 2019 respectively. In October 2021, the MoPSC issued an order approving Ameren Missouri’s request to implement the 2023 program year of its MEEIA 2019 program. The order established performance incentives that would provide Ameren Missouri an opportunity to earn additional revenues, including $13 million if Ameren Missouri achieves certain energy-efficiency goals during the 2023 program year. Ameren Missouri intends to invest $75 million in energy-efficiency programs during the 2023 program year. Extension of PGA Recovery In October 2021, the MoPSC issued an order allowing Ameren Missouri to extend the collection period for the cumulative PGA under- recovery as of August 2021, which includes the February 2021 under-recovery of $53 million, from 12 months to 36 months beginning November 2021, to lessen the impact on customer rates. Similar to other deferrals under the PGA, the deferral associated with the February 2021 under-recovery earns carrying costs at short-term interest rates. 107 Illinois IETL The IETL was enacted in September 2021. The IETL resulted in changes to the regulatory framework applicable to Ameren Illinois’ electric distribution business by giving Ameren Illinois the option to file an MYRP with the ICC by mid-January 2023, with rates effective beginning in 2024, among other things. Ameren Illinois has the option to file for an MYRP every four years. Subject to a constructive outcome regarding the ICC’s determination of performance metrics, Ameren Illinois anticipates filing an MYRP for rates effective beginning in 2024. If it does not file by mid-January 2023, its next opportunity to file an MYRP would be for rates effective beginning in 2028. Ameren Illinois expects to continue to use the current IEIMA performance-based formula ratemaking framework to establish annual customer rates effective through 2023 and reconcile the related revenue requirements. In order to utilize the IEIMA reconciliation, Ameren Illinois must file either a traditional regulatory rate review or an MYRP pursuant to the IETL by mid-January 2023. Under the MYRP, the ICC would approve base rates for electric distribution service to be charged to customers for each calendar year of a four-year period. The base rates for a particular calendar year would be based on forecasted recoverable costs and an ICC-determined ROE applied to Ameren Illinois’ forecasted average annual rate base using a forecasted capital structure, with a common equity ratio of up to 50% being deemed prudent and reasonable by law and a higher equity ratio requiring specific ICC approval. The ROE determined by the ICC is applicable to each calendar year of the four-year period. Under a traditional regulatory rate review, the revenue requirement may be based on a future test year and would include an ROE determined by the ICC. 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. The MYRP would also allow Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis, subject to a reconciliation cap, which provides that the actual revenue requirement does not exceed 105% of the annual revenue requirement approved by the ICC. Certain variations from forecasted costs would be excluded from the reconciliation cap, including those associated with major storms; new business and facility relocations; changes in the timing of expenditures or investments into or out of the applicable calendar year; and changes in interest rates, income taxes, taxes other than income taxes, pension and other post-retirement benefits costs, and amortization of certain regulatory assets. The reconciliation cap would also exclude costs recovered through riders outside of base rates, such as riders for electric energy-efficiency investments, power procurement and transmission services, renewable energy credit compliance, zero emission credits, certain environmental costs, and bad debt write-offs, among others. The actual revenue requirement for a particular year would incorporate Ameren Illinois’ year-end rate base and actual capital structure for such year, provided that the common equity ratio in such capital structure may not exceed that approved by the ICC in the MYRP. Additionally, the ICC- determined ROE in the MYRP would be subject to annual adjustments during the four-year period based on certain performance metrics relating to delivery system reliability, supplier diversity, affordability of customer delivery service cost, customer service performance, timeliness of response to customer requests for interconnection of distributed energy resources, and reductions in peak load due to demand response programs, 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. The ICC is required to issue an order on this matter by September 30, 2022. Excluding potential phase-in of the initial rate increase discussed below, if a given year’s revenue amount collected from customers varies from the approved revenue requirement, an adjustment would be made to electric operating revenues with an offset to a regulatory asset or liability to reflect that year’s actual revenue requirement, independent of actual sales volumes. The regulatory balance would then be collected from, or refunded to, customers within two years from the end of the applicable annual period. Under an MYRP, the IETL permits any initial rate increase to be phased in, with at least 50% of the first annual period’s approved rate increase reflected in rates in the first annual period, with the remaining portion deferred as a regulatory asset and collected from customers over a period not to exceed two years beginning within one year after the second annual period’s rates are effective. Ameren Illinois recognizes revenues when amounts are expected to be collected from customers within two years from the end of an applicable year. The IETL contains other provisions in addition to the ratemaking impacts discussed above. The law permits Ameren Illinois to invest up to $20 million in each of two solar generation and battery storage pilot projects in Illinois. Additionally, the law increases the existing customer surcharge for renewable energy resources, which funds IPA renewable energy credit procurement events. As a result, Ameren Illinois expects additional annual revenues of approximately $100 million to be collected, beginning in February 2022, under the rider for renewable energy credit compliance. It also establishes an Energy Transition Assistance Fund to support economic and workforce development programs designed to assist the state of Illinois with its transition to clean energy sources. The fund will be subsidized through customer surcharges collected by electric utilities operating in the state, including Ameren Illinois, and will be remitted in the month following collection to an Illinois state agency. Ameren Illinois expects to collect up to $25 million annually related to this fund, beginning in January 2022. The IETL also requires Ameren Illinois to file a multi-year integrated grid plan with the ICC to ensure electric distribution infrastructure investments align with the state of Illinois’ renewable energy, climate, and environmental goals, and to support grid modernization, clean energy, and energy efficiency, while providing electric distribution service to customers at affordable rates, among other things. The first multi-year 108 integrated grid plan is required to be filed by mid-January 2023, with the next filing required by mid-January 2026, and every four years thereafter. See Note 14 – Commitments and Contingencies for additional information on emission standards established by the IETL that will limit the operations of Ameren Missouri’s natural gas-fired energy centers located in the state of Illinois. Electric Distribution Service Rate Reconciliation Tariff In March 2021, the ICC issued an order approving Ameren Illinois’ requested tariff to reconcile its electric distribution service revenue requirement once Ameren Illinois ceases to update customer rates under performance-based formula ratemaking. The last update under such ratemaking is anticipated to be for 2023 customer rates. The tariff would allow Ameren Illinois to reconcile its revenue requirement for customer rates established for 2022 and 2023. To utilize the reconciliation, Ameren Illinois is required to file a request to update its electric distribution service rates through either a traditional regulatory rate review, which may be based on a future test year and would reflect a proposed ROE subject to ICC approval, or through the filing of an MYRP, which Ameren Illinois expects to file for rates effective beginning in 2024 pursuant to the IETL as described above. The rate update request would need to be filed by mid-January 2023. Pursuant to the order, Ameren Illinois’ 2022 and 2023 revenues would reflect each year’s actual recoverable costs, year-end rate base, and a return at the applicable WACC, with the ROE component based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The revenue requirement reconciliation adjustment would be collected from, or refunded to, customers within two years from the end of the reconciled year. Electric Distribution Service Rates Under IEIMA In December 2021, 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. This order reflected an increase to the annual performance-based formula rate based on 2020 actual recoverable costs and expected net plant additions for 2021, an increase to include the 2020 revenue requirement reconciliation adjustment including a capital structure composed of 51% common equity, and an increase for the conclusion of the 2019 revenue requirement reconciliation adjustment, which was fully refunded to customers in 2021, consistent with the ICC’s December 2020 annual update filing order. Electric Customer Energy-Efficiency Investments In December 2021, the ICC issued an order in Ameren Illinois’ annual update filing that approved electric customer energy-efficiency rates of $61 million beginning in January 2022, which represents an increase of $10 million from 2021 rates. In July 2021, the ICC issued an order approving Ameren Illinois’ energy-efficiency plan that includes annual investments in electric energy-efficiency programs of approximately $100 million per year from 2022 through 2025. Pursuant to the IETL, the planned annual investments in electric energy-efficiency programs will increase to approximately $120 million. Ameren Illinois expects to file a revised energy-efficiency plan with the ICC by early March 2022 to reflect the expected increased level of annual investments. 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. QIP Reconciliation Hearings In March 2021, the ICC issued an order approving Ameren Illinois’ QIP reconciliation for 2018. The ICC also found that Ameren Illinois’ natural gas capital investments recovered under the QIP during 2018 were accurate and prudent. The ICC order effectively dismissed the Illinois Attorney General’s office challenge with respect to 2018 capital investments. In March 2020, Ameren Illinois filed a 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 2019. In August 2021, the Illinois Attorney General’s office challenged the recovery of capital investments that were made during 2019, 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 2019. 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’ 2019 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. 109 Service Disconnection Moratorium From March 2020 through March 2021, the ICC limited disconnection activities and late fees for customer nonpayment to varying degrees based on customer class. In March 2021, the ICC issued an order allowing Ameren Illinois to resume disconnection activities for all residential customers through a phased-in approach, which began in April 2021 for customers with the largest past due balances and in June 2021 for all remaining residential customers. The March 2021 order also required Ameren Illinois to offer deferred payment arrangements extending to 18 months to all residential customers through June 2021. In addition, the order requires Ameren Illinois to extend the financial assistance program established by a June 2020 ICC order through 2021. Ameren Illinois is allowed to recover up to $4 million in costs incurred during 2021 related to this financial assistance program. These costs will be deferred as regulatory assets and the portion associated with Ameren Illinois’ electric distribution business will be recovered through its bad debt rider and the portion associated with its natural gas distribution business will be recovered through a special purpose rider. Federal Transmission Formula Rate Revisions In February 2020, the MISO, on behalf of Ameren Missouri, Ameren Illinois, and ATXI, filed requests with the FERC to revise each company’s 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. In June 2020, Ameren Missouri, Ameren Illinois, and ATXI filed requests for rehearing arguing, among other things, the revisions should be applied retrospectively to include the period January 1, 2019, to June 1, 2020, and that the FERC should not require refunds for periods prior to 2019. In July 2020, the FERC denied the rehearing requests without addressing the issues raised. In July 2020, Ameren Missouri, Ameren Illinois, and ATXI filed an appeal of the July 2020 rehearing denials to the United States Court of Appeals for the District of Columbia Circuit, which is under no deadline to address the appeal. In October 2020, the FERC issued an order reaffirming its May 2020 order and denying the arguments raised in the rehearing requests filed by Ameren Missouri, Ameren Illinois, and ATXI. In November 2020, Ameren Missouri, Ameren Illinois, and ATXI filed an appeal of the October 2020 order to the United States Court of Appeals for the District of Columbia Circuit. The court of appeals is under no deadline to address either appeal. Regardless of the outcome of the appeal, the impacts of the May 2020 and October 2020 orders were immaterial to Ameren’s, Ameren Missouri’s, or Ameren Illinois’ results of operations, financial position, or liquidity. 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. In April 2021, Ameren Illinois filed a request for rehearing with the FERC regarding its March 2021 order. In May 2021, the FERC denied the rehearing request without addressing the issues raised. In July 2021, Ameren Illinois filed an appeal of the March 2021 order and the May 2021 rehearing denial to the United States Court of Appeals for the District of Columbia Circuit. In August 2021, the United States Court of Appeals for the District of Columbia Circuit granted a motion to consolidate the July 2021, July 2020, and November 2020 appeals. In November 2021, the FERC issued an order reaffirming its March 2021 order and denying the arguments raised in the rehearing request filed by Ameren Illinois. In December 2021, Ameren Illinois filed an appeal of the November 2021 order to the United States Court of Appeals for the District of Columbia Circuit. In December 2021, Ameren Illinois filed a motion to consolidate the December 2021 appeal with the July 2020, November 2020, and July 2021 appeals. In January 2022, the United States Court of Appeals for the District of Columbia issued an order granting the motion to consolidate the appeals. The court is under no deadline to address the appeal. FERC Complaint Cases In November 2013, a customer group filed a complaint case with the FERC seeking a reduction in the allowed base ROE for FERC- regulated transmission rate base under the MISO tariff from 12.38% to 9.15%. In September 2016, the FERC issued an order in the November 2013 complaint case, which lowered the allowed base ROE to 10.32%, or a 10.82% total allowed ROE with the inclusion of a 50 basis point incentive adder for participation in an RTO, that was effective from late September 2016 forward. The September 2016 order also required refunds for the period November 2013 to February 2015, which were paid in 2017. In November 2019, the FERC issued an order addressing the November 2013 complaint case, which set the allowed base ROE at 9.88%, superseding the 10.32% previously ordered, and required refunds, with interest, for the periods November 2013 to February 2015 and from late September 2016 forward. In December 2019, the MISO transmission owners, including Ameren Missouri, Ameren Illinois, and ATXI, filed requests for rehearing with the FERC. In May 2020, the FERC issued an order addressing the requests for rehearing, which set the allowed base ROE at 10.02%, superseding the 9.88% previously ordered, and required refunds, with interest, for the 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 ATXI filed 110 an appeal of the May 2020 order to the United States Court of Appeals 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. As of December 31, 2021, Ameren and Ameren Illinois had substantially paid the refunds, including interest, associated with the allowed base ROE set by the May 2020 order in the November 2013 complaint case. The increase in the FERC-allowed base ROE resulting from the May 2020 order was not material to Ameren Missouri’s results of operations, financial position, or liquidity. 111 Regulatory Assets and Liabilities The following table presents our regulatory assets and regulatory liabilities at December 31, 2021 and 2020: Ameren Missouri 2021 Ameren Illinois Ameren Ameren Missouri 2020 Ameren Illinois Ameren Regulatory assets: $ Under-recovered FAC(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Under-recovered PGA(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MTM derivative losses(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IEIMA revenue requirement reconciliation adjustment(e)(f) . . . . . . . . . . . . . . . . . . . FERC revenue requirement reconciliation adjustment(g) . . . . . . . . . . . . . . . . . . . . Under-recovered VBA(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes(i) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bad debt rider(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Callaway refueling and maintenance outage costs(k) . . . . . . . . . . . . . . . . . . . . . . . Unamortized loss on reacquired debt(l) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Environmental cost riders(m) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Storm costs(f)(n) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Allowance for funds used during construction for pollution control equipment(f)(o) . . . Customer generation rebate program(f)(p) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PISA(f)(q) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . FEJA energy-efficiency rider(f)(r) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47 49 77 — — — 115 — 14 50 — — 13 — 244 — 41 $ — $ 114 125 42 18 17 69 8 — 13 70 17 — 47 — 350 42 $ 47 163 202 42 43 17 185 8 14 63 70 17 13 47 244 350 83 48 — 21 — — — 117 — 39 52 — — 15 — 78 — 37 $ — $ 2 200 — 28 11 65 11 — 22 93 7 — 17 — 283 40 48 2 221 — 50 11 183 11 39 74 93 7 15 17 78 283 77 Total regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 650 $ 932 $ 1,608 $ 407 $ 779 $ 1,209 Less: current regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (127) (180) (319) (60) (37) (109) $ $ Noncurrent regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory liabilities: Over-recovered FAC(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Over-recovered Illinois electric power costs(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Over-recovered PGA(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MTM derivative gains(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IEIMA revenue requirement reconciliation adjustment(e) . . . . . . . . . . . . . . . . . . . . FERC revenue requirement reconciliation adjustment(g) . . . . . . . . . . . . . . . . . . . . Income taxes(i) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost of removal(s) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . AROs(t) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bad debt rider(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and postretirement benefit costs(u) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and postretirement benefit costs tracker(v) . . . . . . . . . . . . . . . . . . . . . . . . Renewable energy credits and zero emission credits(w) . . . . . . . . . . . . . . . . . . . . . RESRAM(x) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Excess income taxes collected in 2018(y) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 523 $ 752 $ 1,289 $ 347 $ 742 $ 1,100 $ 19 — — 50 — — 1,208 1,028 603 — 399 28 — 19 25 32 $ — 13 1 41 — 2 770 929 — 19 392 — 246 — — 15 19 13 1 91 — 4 2,066 1,988 603 19 791 28 246 19 25 48 $ $ 10 — 7 11 — — 1,317 1,027 436 — 198 55 — 2 45 28 $ — 15 15 10 22 21 790 873 — 5 177 — 200 — — 23 10 15 22 21 22 21 2,192 1,923 436 5 375 55 200 2 45 59 Total regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3,411 $ 2,428 $ 5,961 $ 3,136 $ 2,151 $ 5,403 Less: current regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (57) (54) (113) (26) (88) $ (121) Noncurrent regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3,354 $ 2,374 $ 5,848 $ 3,110 $ 2,063 $ 5,282 (a) (b) (c) Under-recovered or over-recovered fuel costs to be recovered or refunded through the FAC. Specific accumulation periods aggregate the under-recovered or over- recovered costs over four months, any related adjustments that occur over the following four months, and the recovery from, or refund to, customers that occurs over the next eight months. Under-recovered or over-recovered costs from utility customers. Amounts will be recovered from, or refunded to, customers within one year of the deferral. 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, for the month of February 2021, Ameren Missouri and Ameren Illinois had under-recovered costs under their PGA clauses of $53 million and $221 million, respectively. Pursuant to an October 2021 MoPSC order, the collection period for Ameren Missouri’s cumulative PGA under-recovery as of August 2021, which includes the February 2021 under-recovery, was extended from 12 months to 36 months, beginning November 2021. Ameren Illinois is collecting its February 2021 PGA under- recovery over 18 months beginning April 2021, but the collection of the remaining balance may be extended at Ameren Illinois’ election to lessen the impact on customer rates. 112 (d) (e) (f) (g) (h) (i) (j) Deferral of commodity-related derivative MTM losses or gains. See Note 7 – Derivative Financial Instruments for additional information. The difference between Ameren Illinois’ electric distribution service annual revenue requirement calculated under the performance-based formula ratemaking framework and the revenue requirement included in customer rates for that year. Any under-recovery or over-recovery will be recovered from, or refunded to, customers with interest within two years. These assets earn a return at the applicable WACC. Ameren Illinois’ and ATXI’s annual revenue requirement reconciliation calculated pursuant to the FERC’s electric transmission formula ratemaking framework. Any under- recovery or over-recovery will be recovered from, or refunded to, customers within two years. Under-recovered natural gas revenue caused by sales volume deviations from weather normalized sales approved by the ICC in rate regulatory reviews. Each year’s amount will be recovered from customers from April through December of the following year. The regulatory assets represent amounts that will be recovered from customers for deferred income taxes related to the equity component of allowance for funds used during construction and the effects of tax rate increases. The regulatory liabilities represent amounts that will be refunded to customers for deferred income taxes related to depreciation differences, other tax liabilities, and the unamortized portion of investment tax credits recorded at rates in excess of current statutory rates. Amounts associated with the equity component of allowance for funds used during construction and the unamortized portion of investment tax credits will be amortized over the expected life of the related assets. For net regulatory liabilities related to deferred income taxes recorded at rates other than the current statutory rate, the weighted- average remaining amortization periods at Ameren, Ameren Missouri, and Ameren Illinois are 35, 28, and 42 years. A rider for the difference between the level of bad debt write-offs, net of any subsequent recoveries, incurred by Ameren Illinois and the level of such costs included in electric distribution and natural gas delivery service rates. Pursuant to a June 2020 ICC order, Ameren Illinois’ electric distribution bad debt rider provided for the recovery of bad debt expense in 2020. The under-recovery or over-recovery for each year is recovered from, or refunded to, customers over a twelve-month period beginning June the following year. (k) Maintenance expenses related to scheduled refueling and maintenance outages at Ameren Missouri’s Callaway Energy Center. Amounts are amortized over the period (l) (m) (n) (o) (p) (q) (r) (s) (t) between refueling and maintenance outages, which has historically been approximately 18 months. Losses related to reacquired debt. These amounts are being amortized over the lives of the related new debt issuances or the original lives of the old debt issuances if no new debt was issued. The recoverable portion of accrued environmental site liabilities that will be collected from electric and natural gas customers through ICC-approved cost recovery riders. The period of recovery will depend on the timing of remediation expenditures. See Note 14 – Commitments and Contingencies for additional information. Storm costs from 2018, 2020, and 2021 deferred in accordance with the IEIMA. These costs are being amortized over five-year periods beginning in the year the storm occurred. The MoPSC’s May 2010 electric rate order allowed Ameren Missouri to record an allowance for funds used during construction for pollution control equipment at its Sioux Energy Center until the cost of that equipment was included in customer rates beginning in 2011. These costs are being amortized over the expected life of the Sioux Energy Center through 2028. Costs associated with Ameren Illinois’ customer generation rebate program. Costs are amortized over a 15-year period, beginning in the year rebates are paid. Under the PISA, Ameren Missouri is permitted 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. Accumulated PISA deferrals are added to rate base prospectively and amortized over a period of 20 years following a regulatory rate review. The electric energy-efficiency investments are being amortized over their weighted-average useful lives beginning in the period in which they were made, with current remaining amortization periods ranging from 5 to 13 years. Estimated funds collected from customers to pay for the future removal cost of property, plant, and equipment retired from service, net of salvage. The ARO regulatory liability includes the nuclear decommissioning trust fund balance ($1,159 million and $982 million at December 31, 2021 and 2020, respectively), net of recoverable removal costs for AROs ($556 million and $546 million at December 31, 2021 and 2020, respectively). See Note 1 – Summary of Significant Accounting Policies – Asset Retirement Obligations. (u) Over-recovered costs are being amortized in proportion to the recognition of prior service costs (credits) and actuarial losses (gains) attributable to Ameren’s pension plan (v) (w) (x) (y) and postretirement benefit plans. See Note 10 – Retirement Benefits for additional information. A regulatory recovery mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri and the level of such costs included in customer rates. The period of refund varies based on MoPSC approval in a regulatory rate review. The weighted-average remaining amortization period is five years. Funds collected for the purchase of renewable energy credits and zero emission credits through IPA procurements. The balance will be amortized as the credits are purchased. Over-recovered costs associated with Ameren Missouri’s compliance with the state of Missouri’s renewable energy standard. Under-recovered or over-recovered costs are aggregated over a twelve-month period beginning each August and are amortized over a twelve-month period beginning February the following year. The excess amount collected in rates related to the TCJA from January 1, 2018, through July 31, 2018. The regulatory liability is being amortized over a three-year period, which began in April 2020. 113 NOTE 3 – PROPERTY, PLANT, AND EQUIPMENT, NET The following table presents components of “Property, plant, and equipment, net” at December 31, 2021 and 2020: 2021 Property, plant, and equipment at original cost:(a) Electric generation: Coal(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Renewable(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Less: Accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Construction work in progress: Nuclear fuel in process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Plant to be abandoned, net(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Property, plant, and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2020 Property, plant, and equipment at original cost:(a) Electric generation: Coal(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Renewable(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric transmission . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Construction work in progress: Nuclear fuel in process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Property, plant, and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri Ameren Illinois Other Ameren 3,955 1,105 5,615 1,889 7,286 1,628 607 1,584 23,669 9,784 13,885 133 674 604 $ $ — — — — 7,017 4,105 3,586 1,183 15,891 4,100 11,791 — 432 — $ — — — — — 1,800 — 242 2,042 330 1,712 — 30 — 3,955 1,105 5,615 1,889 14,303 7,533 4,193 3,009 41,602 14,214 27,388 133 1,136 604 $ 15,296 $ 12,223 $ 1,742 $ 29,261 $ 4,875 $ 1,097 5,608 1,301 6,784 1,482 561 1,390 23,098 9,689 13,409 75 395 13,879 $ $ — — — — 6,649 3,575 3,308 1,070 14,602 3,780 10,822 — 379 11,201 $ — — — — — 1,774 — 245 2,019 304 1,715 — 12 1,727 $ $ 4,875 1,097 5,608 1,301 13,433 6,831 3,869 2,705 39,719 13,773 25,946 75 786 26,807 (a) (b) (c) The estimated lives for each asset group are as follows: 5 to 72 years for electric generation, excluding Ameren Missouri’s hydroelectric generating assets, which have useful lives of up to 150 years; 20 to 80 years for electric distribution; 50 to 75 years for electric transmission; 20 to 80 years for natural gas; and 2 to 55 years for other. Includes $29 million and $36 million of oil-fired generation at December 31, 2021 and 2020, respectively. Original cost amounts include two CTs that have related financing obligations. The gross cumulative asset value of those agreements was $243 million and $240 million at December 31, 2021 and 2020, respectively. The total accumulated depreciation associated with the two CTs was $105 million and $99 million at December 31, 2021 and 2020, respectively. See Note 5 – Long-term Debt and Equity Financings for additional information on these agreements. Renewable includes hydroelectric, wind, solar, and methane gas generation facilities. (d) (e) Other property, plant, and equipment includes assets used to support electric and natural gas services. (f) Represents the net book value of the Rush Island Energy Center and related construction work in progress as Ameren Missouri expects to retire the energy center significantly in advance of its previously expected useful life and in the near term. See Plant to be Abandoned, Net under Note 1 – Summary of Significant Accounting Policies and NSR and Clean Air Act Litigation under Note 14 – Commitments and Contingencies for additional information on the planned accelerated retirement of the Rush Island Energy Center. 114 Capitalized software costs are classified within “Property, Plant, and Equipment, Net” on the balance sheet and are amortized on a straight-line basis over the expected period of benefit, ranging from 2 to 15 years. The following table presents the amortization, gross carrying value, and related accumulated amortization of capitalized software by year: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 125 $ 93 $ Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66 53 44 45 78 30 45 $ 1,199 $ 1,021 $ (757) $ 523 452 398 397 (255) (291) (640) (189) (238) Amortization Expense 2020 2019 2021 Gross Carrying Value 2020 2021 Accumulated Amortization 2021 2020 Annual amortization expense for capitalized software placed in service as of December 31, 2021, is estimated to be as follows: Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 135 $ 119 $ Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75 56 69 47 $ 87 54 31 $ 47 31 14 21 14 6 2022 2023 2024 2025 2026 NOTE 4 – SHORT-TERM DEBT AND LIQUIDITY The liquidity needs of the Ameren Companies are typically supported through the use of available cash, drawings under committed credit agreements, commercial paper issuances, and/or, in the case of Ameren Missouri and Ameren Illinois, short-term affiliate borrowings. Short-Term Borrowings In December 2021, the Credit Agreements, which were scheduled to mature in December 2024, were extended and now mature in December 2025. The Credit Agreements provide $2.3 billion of credit cumulatively through maturity. The total facility size of the Missouri Credit Agreement and Illinois Credit Agreement is $1.2 billion and $1.1 billion, respectively. The maturity date may be extended by an additional one-year period upon the mutual consent of the borrowers and the lenders. Credit available under the agreements is provided by 22 international, national, and regional lenders, with no single lender providing more than $130 million of credit in aggregate. The obligations of each borrower under the respective Credit Agreements to which it is a party are several and not joint. Except under limited circumstances relating to expenses and indemnities, the obligations of Ameren Missouri and Ameren Illinois under the respective Credit Agreements are not guaranteed by Ameren (parent) or any other subsidiary of Ameren. The following table presents the maximum aggregate amount available to each borrower under each facility: Ameren (parent) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 900 $ 850 (a) 500 (a) 800 Missouri Credit Agreement Illinois Credit Agreement (a) Not applicable. The borrowers have the option to seek additional commitments from existing or new lenders to increase the total facility size of the Credit Agreements to a maximum of $1.4 billion for the Missouri Credit Agreement and $1.3 billion for the Illinois Credit Agreement. Ameren (parent) borrowings are due and payable no later than the maturity date of the Credit Agreements. Ameren Missouri and Ameren Illinois borrowings under the applicable Credit Agreement are due and payable no later than the earlier of the maturity date or 364 days after the date of the borrowing. The obligations of the borrowers under the Credit Agreements are unsecured. Loans are available on a revolving basis under each of the Credit Agreements. Funds borrowed may be repaid and, subject to satisfaction of the conditions to borrowing, reborrowed from time to time. At the election of each borrower, the interest rates on such loans will be the alternate base rate plus the margin applicable to the particular borrower and/or the eurodollar rate plus the margin applicable to the particular borrower. The applicable margins will be determined by the borrower’s long-term unsecured credit ratings or, if no such ratings are in effect, the borrower’s corporate/issuer ratings then in effect. The borrowers have received commitments from the lenders to issue letters of credit up to $100 million under each of the Credit Agreements. In addition, the issuance of letters of credit is subject to the $2.3 billion overall combined facility borrowing limitations of the Credit Agreements. The borrowers will use the proceeds from any borrowings under the Credit Agreements for general corporate purposes, including working capital, commercial paper liquidity support, loan funding under the Ameren money pool arrangements, and other short-term affiliate 115 loan arrangements. The Missouri Credit Agreement and the Illinois Credit Agreement are available to support issuances under Ameren (parent)’s, Ameren Missouri’s and Ameren Illinois’ commercial paper programs, respectively, subject to borrowing sublimits, as well as to support issuance of letters of credit for the borrowers. As of December 31, 2021, 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 $1.8 billion. The following table summarizes the activity and relevant interest rates for Ameren (parent)’s, Ameren Missouri’s, and Ameren Illinois’ commercial paper issuances and borrowings under the Credit Agreements in the aggregate for the years ended December 31, 2021 and 2020: Ameren (parent) Ameren Missouri Ameren Illinois Ameren Consolidated 2021 Average daily amount outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial paper issuances outstanding at period-end . . . . . . . . . . . . . . . . Weighted-average interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Peak amount outstanding during period(a) . . . . . . . . . . . . . . . . . . . . . . . . . . Peak interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2020 Average daily amount outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial paper issuances outstanding at period-end . . . . . . . . . . . . . . . . Weighted-average interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Peak amount outstanding during period(a) . . . . . . . . . . . . . . . . . . . . . . . . . . Peak interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ 387 277 0.22 % 650 0.38 % 108 490 1.04 % 490 3.30 % $ $ $ $ 99 165 0.22 % 546 0.35 % 109 — 1.73 % 573 5.05 % (b) $ $ $ $ 118 103 0.21 % 485 0.35 % 46 — 0.97 % 250 3.40 % $ $ $ $ 604 545 0.22 % 1,134 0.38 % 263 490 1.31 % 908 5.05 % (b) (a) The timing of peak outstanding commercial paper issuances and borrowings under the Credit Agreements varies by company. Therefore, the sum of individual company peak amounts may not equal the Ameren consolidated peak amount for the period. (b) Ameren’s and Ameren Missouri’s peak interest rates were affected by temporary disruptions in the commercial paper market in the first quarter of 2020. Indebtedness Provisions and Other Covenants The information below is a summary of the Ameren Companies’ compliance with indebtedness provisions and other covenants. The Credit Agreements contain conditions for borrowings and issuances of letters of credit. These conditions include the absence of default or unmatured default, material accuracy of representations and warranties (excluding any representation after the closing date as to the absence of material adverse change and material litigation, and the absence of any notice of violation, liability, or requirement under any environmental laws that could have a material adverse effect), and obtaining required regulatory authorizations. In addition, it is a condition for any Ameren Illinois borrowing that, at the time of and after giving effect to such borrowing, Ameren Illinois not be in violation of any limitation on its ability to incur unsecured indebtedness contained in its articles of incorporation. The Credit Agreements also contain nonfinancial covenants, including restrictions on the ability to incur certain liens, to transact with affiliates, to dispose of assets, to make investments in or transfer assets to its affiliates, and to merge with other entities. The Credit Agreements require each of Ameren, Ameren Missouri, and Ameren Illinois to maintain consolidated indebtedness of not more than 65% of its consolidated total capitalization pursuant to a defined calculation set forth in the agreements. As of December 31, 2021, the ratios of consolidated indebtedness to total consolidated capitalization, calculated in accordance with the provisions of the Credit Agreements, were 58%, 49%, and 45%, for Ameren, Ameren Missouri, and Ameren Illinois, respectively. The Credit Agreements contain default provisions that apply separately to each borrower. However, a default of Ameren Missouri or Ameren Illinois under the applicable credit agreement is also deemed to constitute a default of Ameren (parent) under such agreement. Defaults include a cross-default resulting from a default of such borrower under any other agreement covering outstanding indebtedness of such borrower and certain subsidiaries (other than project finance subsidiaries and nonmaterial subsidiaries) in excess of $100 million in the aggregate (including under the other credit agreement). However, under the default provisions of the Credit Agreements, any default of Ameren (parent) under either credit agreement that results solely from a default of Ameren Missouri or Ameren Illinois does not result in a cross-default of Ameren (parent) under the other credit agreement. Further, the Credit Agreements default provisions provide that an Ameren (parent) default under either of the Credit Agreements does not constitute a default by Ameren Missouri or Ameren Illinois. None of the Credit Agreements or financing agreements contain credit rating triggers that would cause a default or acceleration of repayment of outstanding balances. The Ameren Companies were in compliance with the provisions and covenants of the Credit Agreements at December 31, 2021. 116 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. Ameren Missouri, Ameren Illinois, and ATXI may participate in the utility money pool as both lenders and borrowers. Ameren (parent) and Ameren Services may participate in the utility money pool only as lenders. Surplus internal funds are contributed to the money pool from participants. The primary sources of external funds for the utility money pool are the Credit Agreements and the commercial paper programs. The total amount available to the pool participants from the utility money pool at any given time is reduced by the amount of borrowings made by participants, but it is increased to the extent that the pool participants advance surplus funds to the utility money pool or remit funds from other external sources. The availability of funds is also determined by funding requirement limits established by regulatory authorizations. Participants receiving a loan under the utility money pool agreement must repay the principal amount of such loan, together with accrued interest. The rate of interest depends on the composition of internal and external funds in the utility money pool. The average interest rate for borrowing under the utility money pool for the year ended December 31, 2021, was 0.17% (2020 – 0.64%). See Note 13 – Related-party Transactions for the amount of interest income and expense from the utility money pool agreement recorded by Ameren Missouri and Ameren Illinois for the years ended December 31, 2021, 2020, and 2019. 117 NOTE 5 – LONG-TERM DEBT AND EQUITY FINANCINGS The following table presents long-term debt outstanding, including maturities due within one year, as of December 31, 2021 and 2020: 2021 2020 Ameren (Parent): 2.50% Senior unsecured notes due 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3.65% Senior unsecured notes due 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.95% Senior unsecured notes due 2027 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.75% Senior unsecured notes due 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.50% Senior unsecured notes due 2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 450 350 500 450 800 2,550 (2) (15) Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2,533 $ Ameren Missouri: Bonds and notes: 1.60% 1992 Series bonds due 2022(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3.50% Senior secured notes due 2024(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.95% Senior secured notes due 2027(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.50% First mortgage bonds due 2029(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.95% First mortgage bonds due 2030(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.15% First mortgage bonds due 2032(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.90% 1998 Series A bonds due 2033(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.90% 1998 Series B bonds due 2033(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.75% 1998 Series C bonds due 2033(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.50% Senior secured notes due 2034(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.30% Senior secured notes due 2037(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.45% Senior secured notes due 2039(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.90% Senior secured notes due 2042(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.65% Senior secured notes due 2045(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.00% First mortgage bonds due 2048(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.25% First mortgage bonds due 2049(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.625% First mortgage bonds due 2051(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Finance obligations: City of Bowling Green agreement (Peno Creek CT) due 2022(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Audrain County agreement (Audrain County CT) due 2023(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47 $ 350 400 450 465 525 60 50 50 184 300 350 485 400 425 330 550 8 240 5,669 (12) (38) (55) 450 350 — — 800 1,600 (2) (10) 1,588 47 350 400 450 465 — 60 50 50 184 300 350 485 400 425 330 550 16 240 5,152 (12) (36) (8) Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,564 $ 5,096 118 Ameren Illinois: Bonds and notes: 2.70% Senior secured notes due 2022(f)(g) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 0.375% First mortgage bonds due 2023(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.25% Senior secured notes due 2025(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.125% Senior secured notes due 2028(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.80% First mortgage bonds due 2028(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.55% First mortgage bonds due 2030(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.70% Senior secured notes due 2036(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.70% Senior secured notes due 2036(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.80% Senior secured notes due 2043(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.30% Senior secured notes due 2044(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.15% Senior secured notes due 2046(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.70% First mortgage bonds due 2047(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.50% First mortgage bonds due 2049(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.25% First mortgage bonds due 2050(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.90% First mortgage bonds due 2051(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ ATXI: 2.45% Senior unsecured notes due 2036(i) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3.43% Senior unsecured notes due 2050(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Unamortized debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren consolidated long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2021 2020 $ 400 100 300 60 430 375 61 42 280 250 490 500 500 300 350 4,438 (7) (39) (400) 400 — 300 60 430 375 61 42 280 250 490 500 500 300 — 3,988 (6) (36) — 3,992 $ 3,946 75 450 525 (2) (50) 473 12,562 $ — 450 450 (2) — $ $ 448 11,078 (a) (b) (c) (d) (e) (f) (g) (h) These bonds are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture and have a fall-away lien provision similar to that of Ameren Missouri’s senior secured notes. These notes are collaterally secured by first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under the Ameren Missouri mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the 2051 maturity of the 2.625% first mortgage bonds and the restrictions preventing a release date to occur that are attached to certain senior secured notes described in footnote (c) below, Ameren Missouri does not expect the first mortgage lien protection associated with these notes to fall away. Ameren Missouri has agreed that so long as any of the 3.90% senior secured notes due 2042 are outstanding, Ameren Missouri will not permit a release date to occur, and so long as any of the 8.45% senior secured notes due 2039 are outstanding, Ameren Missouri will not optionally redeem, purchase, or otherwise retire in full the outstanding first mortgage bonds not subject to release provisions. These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri bond indenture. They are secured by substantially all Ameren Missouri property and franchises. Payments due related to these financing obligations are paid to a trustee, which is authorized to utilize the cash only to pay equal amounts due to Ameren Missouri under related bonds issued by the city/county and held by Ameren Missouri. The timing and amounts of payments due from Ameren Missouri under the agreements are equal to the timing and amount of bond service payments due to Ameren Missouri, resulting in no net cash flow. The balance of both the financing obligations and the related investments in debt securities, recorded in “Other Assets,” was $248 million and $256 million, respectively, as of December 31, 2021 and 2020. These notes are collaterally secured by first mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any first mortgage bonds issued under its mortgage indenture remain outstanding. Redemption, purchase, or maturity of all first mortgage bonds, including first mortgage bonds currently outstanding and any that may be issued in the future, would result in a release of the first mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the 2051 maturity date of the 2.90% first mortgage bonds, Ameren Illinois does not expect the first mortgage lien protection associated with these notes to fall away. Ameren Illinois has agreed that so long as any of the 2.70% senior secured notes due 2022 are outstanding, Ameren Illinois will not permit a release date to occur. These bonds are first mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture. They are secured by substantially all Ameren Illinois property and franchises. 119 (i) The following table presents the principal maturities schedule for the 2.45% senior unsecured notes due 2036: November 2029 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ November 2036 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 30 45 75 Payment Date Principal Payment (j) The following table presents the principal maturities schedule for the 3.43% senior unsecured notes due 2050: Payment Date Principal Payment August 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ August 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2027 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2030 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2032 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2038 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2043 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August 2050 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 49.5 49.5 49.5 49.5 49.5 49.5 76.5 76.5 450.0 The following table presents the aggregate maturities of long-term debt, including current maturities, at December 31, 2021: 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren (parent)(a)  Ameren Missouri(a)  Ameren Illinois(a) — — 450 — 350 1,750 $ 55 $ 240 350 — — 5,024 400 100 — 300 — 3,638  ATXI(a) $ 2,550 $ 5,669 $ 4,438 $ Ameren Consolidated(a) 505 $ 340 850 300 350 50 — 50 — — 425 525 $ 10,837 13,182 (a) Excludes unamortized discount, premium, and debt issuance costs of $17 million, $50 million, $46 million, and $2 million at Ameren (parent), Ameren Missouri, Ameren Illinois, and ATXI, respectively. 120 All classes of Ameren Missouri’s and Ameren Illinois’ preferred stock are entitled to cumulative dividends, have voting rights, and are not subject to mandatory redemption. The preferred stock of Ameren’s subsidiaries is included in “Noncontrolling Interests” on Ameren’s consolidated balance sheet. The following table presents the outstanding preferred stock of Ameren Missouri and Ameren Illinois, which is redeemable at the option of the issuer, at the prices shown below as of December 31, 2021 and 2020: Ameren Missouri: Without par value and stated value of $100 per share, 25 million shares authorized Shares Outstanding Redemption Price (per share) 2021 2020 $ 13 $ $3.50 Series $3.70 Series $4.00 Series $4.30 Series $4.50 Series $4.56 Series $4.75 Series $5.50 Series A Total 130,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 150,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 213,595 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110.00 104.75 105.625 105.00 110.00 102.47 102.176 110.00 (a) Ameren Illinois: With par value of $100 per share, 2 million shares authorized 4.00% Series 4.08% Series 4.20% Series 4.25% Series 4.26% Series 4.42% Series 4.70% Series 4.90% Series 4.92% Series 5.16% Series 6.625% Series 7.75% Series Total Total Ameren 144,275 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45,224 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 23,655 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16,621 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16,190 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18,429 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73,825 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49,289 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50,000 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101.00 103.00 104.00 102.00 103.00 103.00 104.30 102.00 103.50 102.00 100.00 100.00 $ $ $ $ 4 15 4 21 20 2 1 80 $ 13 4 15 4 21 20 2 1 80 14 $ 14 5 2 5 2 2 2 7 5 5 5 2 5 2 2 2 7 5 5 — — 49 129 $ $ 12 1 62 142 (a) (b) In the event of voluntary liquidation, $105.50. In March 2021, Ameren Illinois redeemed its 6.625% and 7.75% series preferred stock at par. Ameren has 100 million shares of $0.01 par value preferred stock authorized, with no such shares outstanding. Ameren Missouri has 7.5 million shares of $1 par value preference stock authorized, with no such shares outstanding. Ameren Illinois has 2.6 million shares of no par value preferred stock authorized, with no such shares outstanding. Ameren Under the DRPlus and its 401(k) plan, Ameren issued 0.5 million, 0.7 million, and 0.9 million shares of common stock in 2021, 2020, and 2019, respectively, and received proceeds of $47 million, $51 million, and $68 million for the respective years. In addition, Ameren issued 0.5 million, 0.5 million, and 0.8 million shares of common stock valued at $33 million, $38 million, and $54 million in 2021, 2020, 2019, respectively, for no cash consideration in connection with stock-based compensation. In May 2020, Ameren filed a Form S-3 registration statement with the SEC, authorizing the offering of 4 million additional shares of its common stock under the DRPlus, which expires in May 2023. Shares of common stock sold under the DRPlus are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. In October 2020, Ameren, Ameren Missouri, and Ameren Illinois filed a Form S-3 shelf registration statement with the SEC, registering the issuance of an unspecified amount of certain types of securities. This registration statement expires in October 2023. In October 2018, Ameren filed a Form S-8 registration statement with the SEC, authorizing the offering of 4 million additional shares of its common stock under its 401(k) plan. Shares of common stock issuable under the 401(k) plan are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. In May 2021, Ameren entered into an equity distribution sales agreement pursuant to which Ameren may offer and sell from time to time 121 up to $750 million of its common stock through an ATM program, which includes the ability to enter into forward sales agreements. During 2021, Ameren issued 1.8 million shares of common stock and received proceeds of $148 million. These proceeds were net of less than $2 million in compensation paid to selling agents. There were no shares issued through the ATM program for the three months ended December 31, 2021. In September 2021, December 2021, and January 2022, Ameren entered into forward sale agreements under the ATM program with counterparties relating to 0.4 million, 0.5 million, and 0.2 million shares of common stock, respectively. The September 2021, December 2021, and January 2022 forward sale agreements can be settled at Ameren’s discretion on or prior to May 3, 2023, June 30, 2023, and June 30, 2023, respectively. On a settlement date or dates, if Ameren 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 forward sale price was initially $87.87, $87.03, and $88.10 per share, for the September 2021, December 2021, and January 2022 forward sale agreements, respectively. 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 December 31, 2021, Ameren could have settled the September 2021 and December 2021 forward sale agreements with physical delivery of 0.4 million and 0.5 million shares of common stock, respectively, to the counterparty in exchange for cash of $30 million and $41 million, respectively. The forward sale agreements have been classified as equity transactions. In August 2019, Ameren entered into a forward sale agreement with a counterparty relating to 7.5 million shares of common stock. In December 2020, pursuant to the agreement terms, Ameren partially settled the forward sale agreement by physically delivering 5.9 million shares of common stock for cash proceeds of $425 million. In February 2021, Ameren settled the remainder of the forward sale agreement by physically delivering 1.6 million shares of common stock for cash proceeds of $113 million. The proceeds were used to fund a portion of Ameren Missouri’s wind generation investments. See Note 15 – Supplemental Information for additional information about the wind generation facilities. In March 2021, Ameren (parent) issued $450 million of 1.75% senior unsecured notes due March 2028, with interest payable semiannually on March 15 and September 15 of each year, beginning September 15, 2021. Ameren received net proceeds of $447 million which were used for general corporate purposes, including the repayment of short-term debt. In November 2021, Ameren (parent) issued $500 million of 1.95% senior unsecured notes due March 2027, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2022. Ameren received net proceeds of $497 million which were used to repay short-term debt. In April 2020, Ameren (parent) issued $800 million of 3.50% senior unsecured notes due January 2031, with interest payable semiannually on January 15 and July 15 of each year, beginning July 15, 2020. Ameren received net proceeds of $793 million, which were used for general corporate purposes, including to repay outstanding short-term debt, and were used to fund the repayment of Ameren’s $350 million of 2.70% senior unsecured notes, which were redeemed at par plus accrued interest in October 2020. Ameren Missouri In June 2021, Ameren Missouri issued $525 million of 2.15% first mortgage bonds due March 2032, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2022. Ameren Missouri received net proceeds of $521 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. In March 2020, Ameren Missouri issued $465 million of 2.95% first mortgage bonds due March 2030, with interest payable semiannually on March 15 and September 15 of each year, beginning September 15, 2020. Ameren Missouri received net proceeds of $462 million, which were used to repay outstanding short-term debt, including short-term debt that Ameren Missouri incurred in connection with the repayment of $85 million of its 5.00% senior secured notes that matured in February 2020. In October 2020, Ameren Missouri issued $550 million of 2.625% first mortgage bonds due March 2051, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2021. Ameren Missouri received net proceeds of $543 million, which were allocated and used to partially finance the acquisition of two wind generation energy centers. See Note 15 – Supplemental Information for information about the wind generation energy centers. For information on Ameren Missouri’s capital contributions, refer to Capital Contributions in Note 13 – Related-party Transactions. 122 Ameren Illinois In March 2021, Ameren Illinois redeemed its 6.625% and 7.75% series preferred stock at par for $12 million and $1 million, respectively. The preferred stock of Ameren Illinois is reflected in “Noncontrolling Interests” on Ameren’s consolidated balance sheet. In June 2021, Ameren Illinois issued $350 million of 2.90% first mortgage bonds due June 2051, with interest payable semiannually on June 15 and December 15 of each year, beginning December 15, 2021. Ameren Illinois received net proceeds of $345 million, which were used to repay short-term debt. Ameren Illinois intends to allocate an amount equal to the net proceeds to sustainability projects meeting certain eligibility criteria. In June 2021, Ameren Illinois issued $100 million of 0.375% first mortgage bonds due June 2023, with interest payable semiannually on June 15 and December 15 of each year, beginning December 15, 2021. Ameren Illinois received net proceeds of $100 million, which were used to repay short-term debt. In November 2020, Ameren Illinois issued $375 million of 1.55% first mortgage bonds due November 2030, with interest payable semiannually on May 15 and November 15 of each year, beginning May 15, 2021. Ameren Illinois received net proceeds of $371 million, which were used to repay short-term debt. For information on Ameren Illinois’ capital contributions, refer to Capital Contributions in Note 13 – Related-party Transactions. ATXI In November 2021, pursuant to a note purchase agreement, ATXI issued $75 million of its 2.45% senior unsecured notes due 2036, with interest payable semiannually on May 16 and November 16 of each year, beginning May 16, 2022, through a private placement offering exempt from registration under the Securities Act of 1933, as amended. ATXI received net proceeds of $75 million, which were used to refinance a portion of an intercompany long-term note with Ameren (parent) and to repay short-term debt. 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 1933, 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 (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 Ameren Missouri’s and Ameren Illinois’ indentures and articles of incorporation include covenants and provisions related to issuances of first mortgage bonds and preferred stock. Ameren Missouri and Ameren Illinois are required to meet certain ratios to issue additional first mortgage bonds and preferred stock. A failure to achieve these ratios would not result in a default under these covenants and provisions but would restrict the companies’ ability to issue bonds or preferred stock. The following table summarizes the required and actual interest coverage ratios for interest charges, dividend coverage ratios, and bonds and preferred stock issuable as of December 31, 2021, at an assumed interest rate of 5% and dividend rate of 6%. Ameren Missouri . . . Required Interest Coverage Ratio(a) >2.0 Ameren Illinois . . . . . >2.0 Actual Interest Coverage Ratio 3.2 7.3 Bonds Issuable(b) $4,834 Required Dividend Coverage Ratio(c) >2.5 7,697 >1.5 Actual Dividend Coverage Ratio Preferred Stock Issuable 152.4 3.5 $3,418 203 (d) (a) (b) (c) (d) Coverage required on the annual interest charges on first mortgage bonds outstanding and to be issued. Coverage is not required in certain cases when additional first mortgage bonds are issued on the basis of retired bonds. Amount of bonds issuable based either on required coverage ratios or unfunded property additions, whichever is more restrictive. The amounts shown also include bonds issuable based on retired bond capacity of $2,437 million and $643 million at Ameren Missouri and Ameren Illinois, respectively. Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. Preferred stock issuable is restricted by the amount of preferred stock that is currently authorized by Ameren Illinois’ articles of incorporation. Ameren’s indenture does not require Ameren to comply with any quantitative financial covenants. The indenture does, however, include certain cross-default provisions. Specifically, either (1) the failure by Ameren to pay when due and upon expiration of any applicable grace period any portion of any Ameren indebtedness in excess of $25 million, or (2) the acceleration upon default of the maturity of any Ameren indebtedness in excess of $25 million under any indebtedness agreement, including borrowings under the Credit Agreements or the Ameren commercial paper program, constitutes a default under the indenture, unless such past due or accelerated debt is discharged or the acceleration is rescinded or annulled within a specified period. Ameren Missouri and Ameren Illinois and certain other nonregistrant Ameren subsidiaries are subject to Section 305(a) of the Federal 123 Power Act, which makes it unlawful for any officer or director of a public utility, as defined in the Federal Power Act, to participate in the making or paying of any dividend from any funds “properly included in capital account.” The FERC has consistently interpreted the provision to allow dividends to be paid as long as (1) the source of the dividends is clearly disclosed, (2) the dividends are not excessive, and (3) there is no self-dealing on the part of corporate officials. At a minimum, Ameren believes that dividends can be paid by its subsidiaries that are public utilities from net income and retained earnings. In addition, under Illinois law, Ameren Illinois and ATXI may not pay any dividend on their respective stock unless, among other things, their respective earnings and earned surplus are sufficient to declare and pay a dividend after provisions are made for reasonable and proper reserves, or unless Ameren Illinois or ATXI has specific authorization from the ICC. Ameren Illinois’ articles of incorporation require dividend payments on its common stock to be based on ratios of common stock to total capitalization and other provisions related to certain operating expenses and accumulations of earned surplus. Ameren Illinois has made a commitment to the FERC to maintain a minimum 30% ratio of common stock equity to total capitalization. As of December 31, 2021, using the FERC-agreed upon calculation method, Ameren Illinois’ ratio of common stock equity to total capitalization was 54%. ATXI’s note purchase agreements includes financial covenants that require ATXI not to permit at any time (1) debt to exceed 70% of total capitalization or (2) secured debt to exceed 10% of total assets. At December 31, 2021, the Ameren Companies were in compliance with the provisions and covenants contained in their indentures and articles of incorporation, as applicable, and ATXI was in compliance with the provisions and covenants contained in its note purchase agreements. In order for the Ameren Companies to issue securities in the future, they will have to comply with all applicable requirements in effect at the time of any such issuances. Off-Balance-Sheet Arrangements At December 31, 2021, none of the Ameren Companies had any significant off-balance-sheet financing arrangements, other than variable interest entities and the September and December 2021 forward sale agreements relating to common stock. See Note 1 – Summary of Significant Accounting Policies for further detail concerning variable interest entities. NOTE 6 – OTHER INCOME, NET The following table presents the components of “Other Income, Net” in the Ameren Companies’ statements of income for the years ended December 31, 2021, 2020, and 2019: 2021 2020 2019 Ameren: Other Income, Net Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Interest income on industrial development revenue bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-service cost components of net periodic benefit income (a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Other Income, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri: Other Income, Net Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Interest income on industrial development revenue bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-service cost components of net periodic benefit income (a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Other Income, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 43 25 2 136 22 (9) (17) 202 26 25 1 55 3 (4) (7) 99 $ $ $ $ 32 25 4 116 13 (25) (b) (14) 151 $ $ 19 25 1 46 4 (12) (b) (7) $ 76 $ 28 25 8 90 6 (12) (15) 130 19 25 1 18 5 (3) (7) 58 124 2021 2020 2019 Ameren Illinois: Other Income, Net Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-service cost components of net periodic benefit income (a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Other Income, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 17 1 55 6 (5) (8) 66 $ $ 13 3 48 6 (5) (6) 59 $ $ 9 6 47 3 (5) (7) 53 (a) (b) For the years ended December 31, 2021, 2020, and 2019, the non-service cost components of net periodic benefit income were adjusted by amounts deferred of $(7) million, $(4) million, and $29 million, respectively, due to a tracker for the difference between the level of such costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates. Includes $8 million pursuant to Ameren Missouri’s March 2020 electric rate order. NOTE 7 – DERIVATIVE FINANCIAL INSTRUMENTS We use derivatives to manage the risk of changes in market prices for natural gas, power, and uranium, as well as the risk of changes in rail transportation surcharges through fuel oil hedges. Such price fluctuations may cause the following: • • • • an unrealized appreciation or depreciation of our contracted commitments to purchase or sell when purchase or sale prices under the commitments are compared with current commodity prices; market values of natural gas and uranium inventories that differ from the cost of those commodities in inventory; actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays; and actual off-system sales revenues that differ from anticipated revenues. The derivatives that we use to hedge these risks are governed by our risk management policies for forward contracts, futures, options, and swaps. Our net positions are continually assessed within our structured hedging programs to determine whether new or offsetting transactions are required. The goal of the hedging program is generally to mitigate financial risks while ensuring that sufficient volumes are available to meet our requirements. Contracts we enter into as part of our risk management program may be settled financially, settled by physical delivery, or net settled with the counterparty. All contracts considered to be derivative instruments are required to be recorded on the balance sheet at their fair values, unless the NPNS exception applies. See Note 8 – Fair Value Measurements for discussion of our methods of assessing the fair value of derivative instruments. 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 nonderivative 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 December 31, 2021 and 2020, 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. 125 The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of December 31, 2021 and 2020. As of December 31, 2021, these contracts extended through October 2024, October 2026, May 2032, and March 2024 for fuel oils, natural gas, power, and uranium, respectively. Commodity Fuel oils (in gallons) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas (in mmbtu) . . . . . . . . . . . . . . . . . . . . . . . . . . Power (in MWhs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium (pounds in thousands) . . . . . . . . . . . . . . . . . . . . Quantity (in millions, except as indicated) Ameren Missouri 2021 Ameren Illinois 30 35 6 586 — 144 6 — Ameren Ameren Missouri 30 179 12 586 43 33 6 365 2020 Ameren Illinois Ameren — 114 7 — 43 147 13 365 The following table presents the carrying value and balance sheet location of all derivative commodity contracts, none of which were designated as hedging instruments, as of December 31, 2021 and 2020: Commodity Fuel oils Natural gas Power Uranium Balance Sheet Location Other current assets . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . Fuel oils Other current liabilities . . . . . . . . . . . . . Natural gas Power Uranium Other deferred credits and liabilities . . . . Other current liabilities . . . . . . . . . . . . . Other deferred credits and liabilities . . . . Other current liabilities . . . . . . . . . . . . . Other deferred credits and liabilities . . . . Other current liabilities . . . . . . . . . . . . . $ $ $ Total liabilities . . . . . . . . . . . . . . . . . . $ Ameren Missouri 2021 Ameren Illinois Ameren Ameren Missouri 2020 Ameren Illinois Ameren 8 5 7 5 23 1 49 — — 2 1 50 23 1 77 $ $ $ $ — — 28 13 — — 41 — — 6 2 9 108 — 125 $ $ $ $ 8 5 35 18 23 1 90 — — 8 3 59 131 1 202 $ $ $ $ 2 — 1 2 7 — 12 7 2 1 — 3 8 — 21 $ $ $ $ — — 8 2 — — 10 — — 1 1 17 181 — 200 $ $ $ $ 2 — 9 4 7 — 22 7 2 2 1 20 189 — 221 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. 126 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 December 31, 2021. If the gross amounts recognized on the balance sheet were netted with derivative instruments and cash collateral received or posted at December 31, 2020, the net amounts would not be materially different from the gross amounts. Commodity Contracts Eligible to be Offset 2021 Assets: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Liabilities: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Gross Amounts Not Offset in the Balance Sheet Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted(a) Net Amount 49 41 90 77 125 202 $ $ $ $ 15 4 19 15 4 19 $ $ $ $ — — — 47 — 47 $ $ $ $ 34 37 71 15 121 136 (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” on Ameren’s balance sheet and in “Current collateral assets” on Ameren Missouri’s 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 December 31, 2021, if counterparty groups were to fail completely to perform on contracts, Ameren’s, Ameren Missouri’s, and Ameren Illinois’ maximum exposure related to derivative assets, predominantly from financial institutions, was $77 million, $36 million, and $41 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 December 31, 2021, the potential loss after consideration of the application of master netting arrangements or similar agreements and collateral held for Ameren, Ameren Missouri, and Ameren Illinois was $61 million, $23 million, and $38 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 the master netting arrangements or similar agreements, assuming (1) the credit risk-related contingent features underlying these arrangements were triggered and (2) those counterparties with rights to do so requested collateral. As of December 31, 2021, the aggregate fair value of derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that counterparties could require were each immaterial to Ameren, Ameren Missouri, and Ameren Illinois. NOTE 8 – 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. We use various methods to determine fair value, including market, income, and cost approaches. With these approaches, we adopt certain assumptions that market participants would use in pricing the asset or liability, including assumptions about market risk or the risks inherent in the inputs to the valuation. Inputs to valuation can be readily observable, market-corroborated, or unobservable. We use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. Authoritative accounting guidance established a fair value hierarchy that prioritizes the inputs used to measure fair value. All financial assets and liabilities carried at fair value are classified and disclosed in one of the following three hierarchy levels: Level 1 (quoted prices in active markets for identical assets or liabilities): Inputs based on quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities are primarily exchange-traded derivatives, cash and cash equivalents, and listed equity securities. The market approach is used to measure the fair value of equity securities held in Ameren Missouri’s nuclear decommissioning trust fund. Equity securities in this fund are representative of the S&P 500 index, excluding securities of Ameren Corporation, owners and/or operators of nuclear power plants, and the trustee and investment managers. The S&P 500 index comprises stocks of large-capitalization companies. 127 Level 2 (significant other observable inputs): Market-based inputs corroborated by third-party brokers or exchanges based on transacted market data. Level 2 assets and liabilities include certain assets held in Ameren Missouri’s nuclear decommissioning trust fund, including United States Treasury and agency securities, corporate bonds and other fixed-income securities, and certain over-the-counter derivative instruments, including natural gas and financial power transactions. Fixed income securities are valued by using prices from independent industry-recognized data vendors who provide values that are either exchange-based or matrix-based. The fair value measurements of fixed-income securities classified as Level 2 are based on inputs other than quoted prices that are observable for the asset or liability. Examples are matrix pricing, market corroborated pricing, and inputs such as yield curves and indices. Derivative instruments classified as Level 2 are valued by corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets. Our development and corroboration process entails obtaining multiple quotes or prices from outside sources. To derive our forward view to price our derivative instruments at fair value, we average the bid/ask spreads to the midpoints. Additionally, a review of all sources is performed to identify any anomalies or potential errors. Further, we consider the volume of transactions on certain trading platforms in our reasonableness assessment of the averaged midpoints. The value of natural gas derivative contracts is based upon exchange closing prices without significant unobservable adjustments. The value of power derivative contracts is based upon exchange closing prices or the use of multiple forward prices provided by third parties. Level 3 (significant other unobservable inputs): Unobservable inputs that are not corroborated by market data. Level 3 assets and liabilities are valued by internally developed models and assumptions or methodologies that use significant unobservable inputs. Level 3 assets and liabilities include derivative instruments that trade in less liquid markets, where pricing is largely unobservable. We value Level 3 instruments by using pricing models with inputs that are often unobservable in the market, such as certain internal assumptions, quotes or prices from outside sources not supported by a liquid market, or trend rates. We perform an analysis each quarter to determine the appropriate hierarchy level of the assets and liabilities subject to fair value measurements. Financial assets and liabilities are classified in their entirety according to the lowest level of input that is significant to the fair value measurement. All assets and liabilities whose fair value measurement is based on significant unobservable inputs are classified as Level 3. We consider nonperformance risk in our valuation of derivative instruments by analyzing our own credit standing and the credit standing of our counterparties, and by considering any credit enhancements (e.g., collateral). Included in our valuation, and based on current market conditions, is a valuation adjustment for counterparty default derived from market data such as the price of credit default swaps, bond yields, and credit ratings. No material gains or losses related to valuation adjustments for counterparty default risk were recorded at Ameren, Ameren Missouri, or Ameren Illinois in 2021, 2020, or 2019. At December 31, 2021 and 2020, the counterparty default risk valuation adjustment related to derivative contracts was immaterial for Ameren, Ameren Missouri, and Ameren Illinois. 128 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 December 31, 2021 and 2020: Level 1 December 31, 2021 Level 3 Level 2 Total Level 1 December 31, 2020 Level 3 Level 2 Total Assets: Ameren Missouri Derivative assets – commodity contracts: Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total derivative assets – commodity contracts . . . . . . . . . . . . $ Nuclear decommissioning trust fund: Equity securities: 13 $ — $ — $ — 10 — 12 — — — 13 1 23 $ 12 $ 14 $ 13 12 23 1 49 $ — $ — $ 2 $ — 2 — 3 — — — 5 — $ 2 $ 3 $ 7 $ 2 3 7 — 12 U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . $ 824 $ — $ — $ 824 $ 680 $ — $ — $ 680 Debt securities: U.S. Treasury and agency securities . . . . . . . . . . . . Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — — 141 131 56 Total nuclear decommissioning trust fund . . . . . . . . . . . . . . . $ Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 824 $ 847 $ 328 $ 340 $ — — — 141 131 56 — $ 1,152 (a) 14 $ 1,201 Ameren Illinois Derivative assets – commodity contracts: Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1 $ 33 $ 7 $ 41 Ameren Derivative assets – commodity contracts(b) . . . . . . . . . . . . . . $ Nuclear decommissioning trust fund(c) . . . . . . . . . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 24 $ 824 848 $ 45 $ 328 373 $ 21 $ — 90 1,152 (a) 21 $ 1,242 — — — 680 $ 682 $ 115 115 67 297 $ 300 $ — — — — $ 7 $ 115 115 67 977 989 (a) — $ 6 $ 4 $ 10 2 $ 9 $ 680 297 682 $ 306 $ 11 $ — 11 $ (a) 22 977 999 $ $ $ $ $ Liabilities: Ameren Missouri Derivative liabilities – commodity contracts: Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — $ — $ — $ — 45 — 2 — — 1 28 1 45 $ 2 $ 30 $ Ameren Illinois Derivative liabilities – commodity contracts: Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — $ — 5 $ 3 $ — 117 Total Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — $ 5 $ 120 $ — 3 73 1 77 8 117 125 Ameren Derivative liabilities – commodity contracts(b) . . . . . . . . . . . . . $ 45 $ 7 $ 150 $ 202 $ 6 $ — $ 3 $ — 8 — 1 — — — 3 — $ 14 $ 1 $ 6 $ 9 1 11 — 21 $ $ $ — $ — — $ 1 $ 1 $ — 198 1 $ 199 $ 2 198 200 14 $ 2 $ 205 $ 221 (a) (b) (c) Balance excludes $7 million and $5 million of cash and cash equivalents, receivables, payables, and accrued income, net for December 31, 2021 and 2020, respectively. See the Ameren Missouri and Ameren Illinois sections of the table for a breakout of the fair value of Ameren’s derivative assets and liabilities by type of commodity. See the Ameren Missouri section of the table for a breakout of Ameren’s nuclear decommissioning trust fund by investment type. See Note 10 – Retirement Benefits for tables that set forth, by level within the fair value hierarchy, Ameren’s pension and postretirement plan assets as of December 31, 2021 and 2020. 129 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 years ended December 31, 2021 and 2020: 2021 2020 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Beginning balance at January 1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2 $ (198) $ (196) $ 13 $ (224) $ (211) Realized and unrealized gains (losses) included in regulatory assets/liabilities . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Change in unrealized gains (losses) related to assets/liabilities held at December 31 . . . . $ (1) (16) (15) $ (14) $ 70 11 69 (5) (117) $ (132) 65 $ 51 $ $ 15 (26) 2 $ 1 $ 8 18 23 (8) (198) $ (196) 9 $ 10 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 December 31, 2021 and 2020: Fair Value Commodity Assets Power(c) $ 13 $ 2021 Liabilities Valuation Technique(s) Unobservable Input(a) (145) Discounted cash flow Average forward peak and off-peak pricing – forwards/ swaps ($/MWh) Nodal basis ($/MWh) Trend rate (%) 2020 Power(c) $ 5 $ (201) Discounted cash flow Average forward peak and off-peak pricing – forwards/ swaps ($/MWh) Nodal basis ($/MWh) Trend rate (%) Range 32 – 55 (14) – 0 0 – 0 23 – 37 (6) – 0 2 – 6 Weighted Average(b) 40 (2) 0 29 (2) 3 (a) Generally, significant increases (decreases) in these inputs in isolation would result in a significantly higher (lower) fair value measurement. (b) (c) Unobservable inputs were weighted by relative fair value. 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. 130 The following table sets forth, by level within the fair value hierarchy, the carrying amount and fair value of financial assets and liabilities disclosed, but not carried, at fair value as of December 31, 2021 and 2020: Carrying Amount Level 1 Fair Value Level 2 December 31, 2021 Level 3 Total 155 $ 155 $ $ — 248 545 13,930 — — — (c) 591 Ameren: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Investments in industrial development revenue bonds(a) . . . . . . . . . . . . . . . . . . Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt (including current portion)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Investments in industrial development revenue bonds(a) . . . . . . . . . . . . . . . . . . Short-term debt Long-term debt (including current portion)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt (including current portion) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Investments in industrial development revenue bonds(a) . . . . . . . . . . . . . . . . . . Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt (including current portion)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Advances to money pool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in industrial development revenue bonds(a) . . . . . . . . . . . . . . . . . . Long-term debt (including current portion)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Borrowings from money pool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt (including current portion) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 248 545 13,067 (b) 8 $ $ $ 248 165 5,619 133 103 4,392 (b) (b) 301 256 490 11,086 (b) 145 139 256 5,104 (b) 147 19 3,946 (b) — — — 8 — — — 133 — — 301 — — — $ — $ 248 165 6,321 — 103 4,971 $ December 31, 2020 $ $ $ $ $ — 256 490 12,778 — 139 256 6,160 — 19 4,822 $ 145 $ — — — $ 147 $ — — $ $ $ $ $ $ 155 248 545 14,521 8 248 165 6,321 133 103 4,971 301 256 490 13,315 145 139 256 6,160 147 19 4,822 — — — — — — — — — — (c) 537 — — — — — — — (a) (b) (c) Ameren and Ameren Missouri have investments in industrial development revenue bonds, classified as held-to-maturity and recorded in “Other Assets,” that are equal to the finance obligations for the Peno Creek and Audrain CT energy centers. As of December 31, 2021 and 2020, the carrying amount of both the investments in industrial development revenue bonds and the finance obligations approximated fair value. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $94 million, $38 million, and $39 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2021. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $84 million, $36 million, and $36 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2020. The Level 3 fair value amount consists of ATXI’s senior unsecured notes. NOTE 9 – CALLAWAY ENERGY CENTER Maintenance Outage During its return to full power after the completion of the last refueling and maintenance outage in late December 2020, the Callaway Energy Center experienced a non-nuclear operating issue related to its generator. After replacement of certain key components of the generator, the energy center returned to service in early August 2021. The cost of generator repairs was approximately $60 million, which was largely capital expenditures. In April 2021, Ameren Missouri’s insurance claims were accepted by NEIL, which covered a significant portion of the capital expenditures and covered lost sales of up to $4.5 million weekly after March 17, 2021. Insurance recoveries related to lost sales were reflected in electric operating revenues and included in net energy costs under the FAC. Expected insurance recoveries related to the capital expenditures were reflected as a reduction to property, plant, and equipment. As of December 31, 2021, a $33 million insurance receivable was included in “Miscellaneous accounts receivable” on Ameren’s and Ameren Missouri’s balance sheets related to the capital expenditures and lost sales insurance claims. In January 2022, Ameren Missouri received $17 million in payments from NEIL and EMANI related to the capital expenditures insurance claims. 131 Spent Nuclear Fuel Under the Nuclear Waste Policy Act of 1982, as amended, the DOE is responsible for disposing of spent nuclear fuel from the Callaway Energy Center and other commercial nuclear energy centers. As required by the act, Ameren Missouri and other utilities have entered into standard contracts with the DOE, which stated that the DOE would begin to dispose of spent nuclear fuel by 1998. However, the DOE failed to fulfill its disposal obligations, and Ameren Missouri and other nuclear energy center owners sued the DOE to recover costs incurred for ongoing storage of their spent fuel. Ameren Missouri’s lawsuit against the DOE resulted in a settlement agreement that provides for annual reimbursement of additional spent fuel storage and related costs. Ameren Missouri received immaterial reimbursements from the DOE in the years ended December 31, 2021, 2020, and 2019. Ameren Missouri will continue to apply for reimbursement from the DOE for allowable costs associated with the ongoing storage of spent fuel. The DOE’s delay in carrying out its obligation to dispose of spent nuclear fuel from the Callaway Energy Center is not expected to adversely affect the continued operations of the energy center. Decommissioning Electric rates charged to customers provide for the recovery of the Callaway Energy Center’s decommissioning costs, which include decontamination, dismantling, and site restoration costs, over the expected life of the nuclear energy center. Amounts collected from customers are deposited into the external nuclear decommissioning trust fund to provide for the Callaway Energy Center’s decommissioning. It is assumed that the Callaway Energy Center site will be decommissioned after its retirement through the immediate dismantlement method and removed from service. The Callaway Energy Center’s operating license expires in 2044. Ameren and Ameren Missouri have recorded an ARO for the Callaway Energy Center decommissioning costs at fair value. Annual decommissioning costs of $7 million are included in the costs used to establish electric rates for Ameren Missouri’s customers. Every three years, the MoPSC requires Ameren Missouri to file an updated cost study and funding analysis for decommissioning its Callaway Energy Center. An updated cost study and funding analysis was filed with the MoPSC in November 2020 and reflected within the ARO. In February 2021, the MoPSC approved no change in electric rates for decommissioning costs consistent with Ameren Missouri’s updated cost study and funding analysis. Ameren and Ameren Missouri have classified the investments in debt and equity securities that are held in the nuclear decommissioning trust fund as available for sale, and have recorded all such investments at their fair market value at December 31, 2021 and 2020. Investments in the nuclear decommissioning trust fund have a target allocation of 60% to 70% in equity securities, with the balance invested in debt securities. The fair value of the trust fund for Ameren Missouri’s Callaway Energy Center is reported as “Nuclear decommissioning trust fund” in Ameren’s and Ameren Missouri’s balance sheets. This amount is legally restricted and may be used only to fund the costs of nuclear decommissioning. Changes in the fair value of the trust fund are recorded as an increase or decrease to the nuclear decommissioning trust fund, with an offsetting adjustment to the regulatory liability related to AROs. This reporting is consistent with the method used to account for the decommissioning costs recovered in rates. See Note 2 – Rate and Regulatory Matters for the regulatory liability recorded at December 31, 2021. If the assumed return on trust assets is not earned, Ameren Missouri believes that it is probable that any additional funding requirements resulting from such earnings deficiency will be recovered in customer rates. The following table presents proceeds from the sale and maturities of investments in Ameren Missouri’s nuclear decommissioning trust fund and the gross realized gains and losses resulting from those sales for the years ended December 31, 2021, 2020, and 2019: Proceeds from sales and maturities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Gross realized gains . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gross realized losses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2021 2020 2019 439 $ 183 $ 32 6 10 3 260 10 2 132 The following table presents the cost and fair value of investments in debt and equity securities in Ameren’s and Ameren Missouri’s nuclear decommissioning trust fund at December 31, 2021 and December 31, 2020: Security Type Cost Gross Unrealized Gain Gross Unrealized Loss Fair Value 2021 Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 320 188 4 3 515 272 198 4 1 475 $ $ $ $ 10 640 — — 650 25 491 — — 516 $ $ $ $ 2 4 — — 6 — 9 — — 9 $ $ $ $ 328 824 4 3 1,159 297 680 4 1 982 (a) Represents net receivables and payables relating to pending securities sales, interest, and securities purchases. The following table presents the costs and fair values of investments in debt securities in Ameren’s and Ameren Missouri’s nuclear decommissioning trust fund according to their contractual maturities at December 31, 2021: Less than 5 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5 years to 10 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Due after 10 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Cost Fair Value 155 $ 71 94 320 $ 156 72 100 328 Insurance The following table presents insurance coverage at Ameren Missouri’s Callaway Energy Center at January 1, 2022: Type and Source of Coverage Public liability and nuclear worker liability: Most Recent Renewal Date Maximum Coverages Maximum Assessments for Single Incidents American Nuclear Insurers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . January 1, 2022 Pool participation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) Property damage: NEIL and EMANI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . April 1, 2021 Accidental outage: NEIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . April 1, 2021 $ $ $ $ 450 13,073 13,523 (a) (c) 3,200 (d) (f) 490 $ $ $ $ (b) — 138 138 (e) 25 (e) 7 (a) (b) (c) (d) (e) (f) 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. 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. Limit of liability for each incident under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended. This limit is subject to change to account for the effects of inflation and changes in the number of licensed power reactors. 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. All NEIL-insured plants could be subject to assessments should losses exceed the accumulated funds from NEIL. Accidental outage insurance provides for lost sales in the event of a prolonged accidental outage. Weekly indemnity up to $4.5 million for 52 weeks, which commences after the first 12 weeks of an outage, plus up to $3.6 million per week for a minimum of 71 weeks thereafter for a total not exceeding the policy limit of $490 million. Nonradiation events are limited to $328 million. The Price-Anderson Act is a federal law that limits the liability for claims from an incident involving any licensed United States commercial nuclear energy center. The limit is based on the number of licensed reactors. The limit of liability and the maximum potential annual payments are adjusted at least every five years for inflation to reflect changes in the Consumer Price Index. The most recent five-year inflationary adjustment became effective in November 2018. Owners of a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by the Price-Anderson Act. 133 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 Ameren’s and Ameren Missouri’s results of operations, financial position, or liquidity. NOTE 10 – RETIREMENT BENEFITS The primary objective of the Ameren pension and postretirement benefit plans is to provide eligible employees with pension and postretirement health care and life insurance benefits. Ameren has defined benefit pension plans covering substantially all of its employees and has a postretirement benefit plan covering non-union employees hired before October 2015 and union employees hired before January 2020. Ameren Missouri and Ameren Illinois each participate in Ameren’s single-employer pension and other postretirement plans. All non- union employees participate in a cash balance pension plan. Ameren Missouri union employees hired after June 2013, and Ameren Illinois union employees hired after mid-October 2012, participate in a cash balance pension plan. Ameren uses a measurement date of December 31 for its pension and postretirement benefit plans. Ameren’s qualified pension plan is the Ameren Retirement Plan. Ameren’s other postretirement plan is the Ameren Retiree Welfare Benefit Plan. Ameren also has an unfunded nonqualified pension plan, the Ameren Supplemental Retirement Plan, which is available to provide certain management employees and retirees with a supplemental benefit when their qualified pension plan benefits are capped in compliance with Internal Revenue Code limitations. Only Ameren subsidiaries participate in the plans listed above. Ameren’s pension and other postretirement benefit plans were overfunded by $717 million and $249 million in the aggregate as of December 31, 2021 and 2020, respectively. These net assets are recorded in “Pension and other postretirement benefits,” “Other current liabilities,” and “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. The increase in the overfunded pension and postretirement benefit plans during 2021 was primarily the result of an increase in the return on plan assets of the pension and postretirement trusts and a 25 basis point increase in the pension and other postretirement benefit plan discount rates used to determine the present value of the obligation. The overfunded pension and other postretirement benefit plans also resulted in regulatory liabilities on Ameren’s, Ameren Missouri’s, and Ameren Illinois’ balance sheets. The following table presents the net benefit liability/(asset) recorded on the balance sheets as of December 31, 2021 and 2020: Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (717) $ (189) (416) (249) (25) (210) 2021 2020 (a) Liabilities associated with pension and other postretirement benefits are recorded in “Other current liabilities” and “Other deferred credits and liabilities” on Ameren’s, Ameren Missouri’s, and Ameren Illinois’ balance sheets. 134 Ameren recognizes the overfunded and underfunded status of its pension and postretirement plans as an asset or a liability on its consolidated balance sheet, with offsetting entries to accumulated OCI and regulatory assets or liabilities. The following table presents the funded status of Ameren’s pension and postretirement benefit plans as of December 31, 2021 and December 31, 2020. It also provides the amounts included in regulatory assets or liabilities and accumulated OCI at December 31, 2021 and December 31, 2020, that have not been recognized in net periodic benefit costs. 2021 2020 Pension Benefits Postretirement Benefits Pension Benefits Postretirement Benefits Accumulated benefit obligation at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,174 $ (a) Change in benefit obligation: Net benefit obligation at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,510 $ 1,204 Service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Participant contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net benefit obligation at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in plan assets: Fair value of plan assets at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actual return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employer contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Participant contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of plan assets at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Funded status – surplus . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134 152 — (82) (257) 5,457 5,510 432 60 — (257) 5,745 (288) Accrued benefit asset at December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (288) $ Amounts recognized in the balance sheet consist of: Noncurrent asset . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Current liability(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncurrent liability(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net asset recognized . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (327) $ 2 37 (288) $ Amounts recognized in regulatory assets or liabilities consist of: Net actuarial gain . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (415) $ Prior service credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amounts recognized in accumulated OCI (pretax) consist of: Net actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — (8) 23 33 9 (80) (60) 1,129 1,453 154 2 9 (60) 1,558 (429) (429) (429) — — (429) (343) (33) 1 $ $ $ $ $ $ 5,213 $ (a) 4,967 $ 1,110 110 174 — 508 (249) 5,510 4,564 1,143 52 — (249) 5,510 — — $ (39) $ 2 37 — $ (138) $ — 5 19 39 8 91 (63) 1,204 1,297 209 2 8 (63) 1,453 (249) (249) (249) — — (249) (200) (37) 6 (231) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (423) $ (375) $ (133) $ (a) (b) (c) Not applicable. Included in “Other current liabilities” on Ameren’s consolidated balance sheet. Included in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. The following table presents the assumptions used to determine our benefit obligations at December 31, 2021 and 2020: Discount rate at measurement date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in future compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash balance pension plan interest crediting rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (initial)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (ultimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension Benefits Postretirement Benefits 2021 2020 2021 2020 3.00 % 2.75 % 3.00 % 2.75 % 3.50 5.00 (a) (a) 3.50 5.00 (a) (a) 3.50 (a) 5.00 5.00 3.50 (a) 5.00 5.00 (a) (b) Not applicable. Initial and ultimate medical cost trend rate for certain Medicare-eligible participants was 2.50% and 3.00% at December 31, 2021 and 2020, respectively. Ameren determines discount rate assumptions by identifying a theoretical settlement portfolio of high-quality corporate bonds sufficient to provide for a plan’s projected benefit payments. The settlement portfolio of bonds is selected from a pool of approximately 820 high-quality corporate bonds. A single discount rate is then determined; that rate results in a discounted value of the plan’s benefit payments that equates 135 to the market value of the selected bonds. During 2021, Ameren elected to continue to use the Society of Actuaries mortality table and the Society of Actuaries 2020 Mortality Improvement Scale. Funding Pension benefits are based on the employees’ years of service, age, and compensation. Ameren’s pension plans are funded in compliance with income tax regulations, federal funding requirements, and other regulatory requirements. As a result, Ameren expects to fund its pension plans at a level equal to the greater of the pension cost or the legally required minimum contribution. Based on its assumptions at December 31, 2021, its investment performance in 2021, and its pension funding policy, Ameren, Ameren Missouri, and Ameren Illinois do not expect to make material contributions in the aggregate over the next five years. These estimated contributions may change based on actual investment performance, changes in interest rates, changes in our assumptions, changes in government regulations, and any voluntary contributions. Our funding policy for postretirement benefits is primarily to fund the Voluntary Employee Beneficiary Association (VEBA) trusts to match the annual postretirement expense. The following table presents the cash contributions made to our defined benefit retirement plans and to our postretirement plan during 2021, 2020, and 2019: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 22 28 10 60 $ $ 17 27 8 $ 3 $ 19 1 52 $ 23 $ 1 1 — 2 $ $ 1 1 — 2 $ $ 1 1 1 3 Pension Benefits Postretirement Benefits 2021 2020 2019 2021 2020 2019 Investment Strategy and Policies Ameren manages plan assets in accordance with the “prudent investor” guidelines contained in ERISA. The investment committee, which includes members of senior management, approves and implements investment strategy and asset allocation guidelines for the plan assets. The investment committee’s goals are twofold: first, to ensure that sufficient funds are available to provide the benefits at the time they are payable; and second, to maximize total return on plan assets and to minimize expense volatility consistent with its tolerance for risk. Ameren delegates the task of investment management to specialists in each asset class. As appropriate, Ameren provides each investment manager with guidelines that specify allowable and prohibited investment types. The investment committee regularly monitors manager performance and compliance with investment guidelines. The expected return on plan assets assumption is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Projected rates of return for each asset class were estimated after an analysis of historical experience, future expectations, and the volatility of the various asset classes. After considering the target asset allocation for each asset class, we reviewed the overall expected rate of return for the portfolio for historical and expected experience of active portfolio management results compared with benchmark returns and for the effect of expenses paid from plan assets. Ameren will use an expected return on plan assets for its pension and postretirement plan assets of 6.50% in 2022. Ameren’s investment committee strives to assemble a portfolio of diversified assets that does not create a significant concentration of risks. The investment committee develops asset allocation guidelines between asset classes, and it creates diversification through investments in assets that differ by type (equity, debt, real estate), duration, market capitalization, country, style (growth or value), and industry, among other factors. The diversification of assets is displayed in the target allocation table below. The investment committee also routinely rebalances the plan assets to adhere to the diversification goals. The investment committee’s strategy reduces the concentration of investment risk; however, Ameren is still subject to overall market risk. Effective January 2020, Ameren’s investment committee developed and implemented a liability hedging investment strategy for its qualified pension plans designed to reduce interest rate risk as part of an objective for its long-term investment strategy. The plan invests in derivative instruments mainly consisting of interest rate futures intended to extend the duration of the pension plan assets so that the assets are more closely aligned with the duration of the liabilities. In addition, part of Ameren’s investment strategy includes participation in a securities lending program, which allows it to lend eligible securities to third party borrowers. All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested in the form of cash, government obligations, and U.S. agency obligations. Ameren’s fair value of securities loaned was $374 million and $365 million as of December 31, 2021 and 2020, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2021 and 2020. 136 The following table presents our target allocations and our pension and postretirement plans’ asset categories as of December 31, 2021 and 2020: Pension Plan: Asset Category Target Allocation 2021(a) Percentage of Plan Assets at December 31, 2021 2020 Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small- and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Global . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Real estate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Private equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Diversified credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Postretirement Plans: Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small- and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Global . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0% – 5% 11% – 21% 3% – 13% 9% – 19% 7% – 17% 45% – 55% 35% – 45% 0% – 10% 0% – 5% 0% – 10% 0% – 7% 23% – 33% 3% – 13% 9% – 19% 5% – 15% 55% – 65% 33% – 43% (a) (b) These target allocations reflect targets that were approved in 2021 to take effect in the subsequent year. Less than 1% of plan assets. 3 % 23 % 9 % 15 % 11 % 58 % 35 % 4 % (b) (b) 100 % 3 % 30 % 9 % 13 % 10 % 62 % 35 % 100 % 1 % 26 % 9 % 15 % 9 % 59 % 36 % 4 % (b) (b) 100 % 3 % 31 % 8 % 15 % 10 % 64 % 33 % 100 % In general, the United States large-capitalization equity investments are passively managed or indexed, whereas the international, global, United States small-capitalization, and United States mid-capitalization equity investments are actively managed by investment managers. Debt securities include a broad range of fixed-income vehicles. Debt security investments in high-yield securities and non-United- States-dollar-denominated securities are owned by the plans, but in limited quantities to reduce risk. Most of the debt security investments are under active management by investment managers. Real estate investments include private real estate vehicles; however, Ameren does not, by policy, hold direct investments in real estate property. In addition to the derivative investments included in the liability hedging investment strategy described above, Ameren’s investment committee also allows investment managers to use derivatives, such as index futures, foreign exchange futures, and options, in certain situations to increase or to reduce market exposure in an efficient and timely manner. Fair Value Measurements of Plan Assets Investments in the pension and postretirement benefit plans were stated at fair value as of December 31, 2021. Fair value is defined as the price that would be received for an asset in the principal or most advantageous market for the asset in an orderly transaction between market participants on the measurement date. Cash and cash equivalents have initial maturities of three months or less and are recorded at cost plus accrued interest. Investments traded in active markets on national or international securities exchanges are valued at closing prices on the measurement date or, if that is not a business day, on the last business day before that date. Securities traded in over-the-counter markets are valued by quoted market prices, broker or dealer quotations, or alternative pricing sources with reasonable levels of price transparency. Investments measured under NAV as a practical expedient are based on the fair values of the underlying assets provided by the funds and their administrators. The fair value of real estate investments is based on NAV; it is determined by annual appraisal reports prepared by an independent real estate appraiser. Investments measured at NAV often provide for daily, monthly, or quarterly redemptions with 60 or less days of notice depending on the fund. For some funds, redemption may also require approval from the fund’s board of directors. Derivative contracts are valued at fair value, as determined by the investment managers (or independent third parties on behalf of the investment managers), who use proprietary models and take into consideration exchange quotations on underlying instruments, dealer quotations, and other market information. 137 The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plans’ assets measured at fair value and NAV as of December 31, 2021 and 2020: Level 1 December 31, 2021 NAV Level 2 Total Level 1 December 31, 2020 NAV Level 2 Total Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Equity securities: U.S. large-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small- and mid-capitalization . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Global . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. Treasury and agency securities . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Real estate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Private equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Less: Medical benefit assets(a) . . . . . . . . . . . . . . . . . . . . . . . . . Plus: Net receivables(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of pension plans’ assets . . . . . . . . . . . . . . . . . . . . . — $ — $ 116 $ 116 $ — $ — $ 145 $ 145 — 558 372 — — — — 17 — — 947 $ — — — — 545 50 1,450 11 — — 2,056 $ 1,381 — 531 621 27 — — — 228 1 2,905 $ 1,381 558 903 621 572 50 1,450 28 228 1 5,908 (234) 71 $ — 513 375 — — — 3 (5) — — 886 $ — — — — 506 50 1,325 8 — — 1,889 $ 1,511 — 492 546 17 — — — 208 2 2,921 $ 1,511 513 867 546 523 50 1,328 3 208 2 5,696 (219) 33 $ 5,745 $ 5,510 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. Receivables related to pending securities sales, offset by payables related to pending securities purchases. (b) The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the postretirement benefit plans’ assets measured at fair value and NAV as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Level 1 Level 2 NAV Total Level 1 Level 2 NAV Total Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 24 $ — $ — $ 24 $ 38 $ — $ — $ 38 Equity securities: U.S. large-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small- and mid-capitalization . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Global . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Plus: Medical benefit assets(a) . . . . . . . . . . . . . . . . . . . . . . . . . Plus: Net receivables(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of postretirement benefit plans’ assets . . . . . . . . . . . 283 113 60 — — — — — — — 133 — 480 $ 133 $ 115 — 117 132 — 335 699 $ 398 113 177 132 133 335 1,312 234 12 279 104 75 — — — — — — — 106 — $ 496 $ 106 $ 107 — 107 120 — 295 629 $ 386 104 182 120 106 295 1,231 219 3 $ 1,558 $ 1,453 (a) Medical benefit (health and welfare) component for accounts maintained in accordance with Section 401(h) of the Internal Revenue Code to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. Receivables related to pending securities sales, offset by payables related to pending securities purchases. (b) 138 Net Periodic Benefit Cost The following table presents the components of the net periodic benefit cost of Ameren’s pension and postretirement benefit plans during 2021, 2020, and 2019: Pension Benefits 2020 2019 2021 Postretirement Benefits 2020 2019 2021 Service cost(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Non-service cost components: 134 $ 110 $ 88 $ 23 $ 19 $ 18 Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152 (297) 174 (291) Amortization of: Prior service credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total non-service cost components(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Net periodic benefit cost (income) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — 73 (72) $ $ 62 (1) 60 (58) $ $ 52 187 (276) (1) 25 (65) 23 33 (80) (4) (6) 39 (80) (4) (9) $ $ (57) $ (34) $ (54) $ (35) $ 43 (77) (5) (15) (54) (36) (a) Service cost, net of capitalization, is reflected in “Operating Expenses - Other operations and maintenance” on Ameren’s statement of income. (b) Non-service cost components are reflected in “Other Income, Net” on Ameren’s consolidated statement of income. See Note 6 – Other Income, Net for additional information. The Ameren Companies are responsible for their share of the pension and postretirement benefit costs. The following table presents the pension costs and the postretirement benefit costs incurred for the years ended December 31, 2021, 2020, and 2019: Pension Costs Postretirement Costs 2021 2020 2019 2021 2020 2019 Ameren Missouri(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 29 34 (1) 22 32 (2) $ 5 $ (4) $ (5) $ 20 (2) (31) 1 (31) 1 62 $ 52 $ 23 $ (34) $ (35) $ (6) (30) — (36) (a) Does not include the impact of the tracker for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri and the level of such costs included in customer rates. The expected pension and postretirement benefit payments from qualified trust and company funds, which reflect expected future service, as of December 31, 2021, are as follows: Pension Benefits Postretirement Benefits Paid from Qualified Trust Funds Paid from Company Funds Paid from Qualified Trust Funds Paid from Company Funds 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2027 – 2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 267 274 279 284 288 1,476 $ 2 2 3 3 3 12 $ 59 60 61 61 60 296 2 2 2 2 2 9 The following table presents the assumptions used to determine net periodic benefit cost for our pension and postretirement benefit plans for the years ended December 31, 2021, 2020, and 2019: Pension Benefits Postretirement Benefits 2021 2020 2019 2021 2020 2019 Discount rate at measurement date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.75 % 3.50 % 4.25 % 2.75 % 3.50 % 4.25 % Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in future compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash balance pension plan interest crediting rate . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (initial)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (ultimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.50 3.50 5.00 (a) (a) 7.00 3.50 5.00 (a) (a) 7.00 3.50 5.00 (a) (a) 6.50 3.50 (a) 5.00 5.00 7.00 3.50 (a) 5.00 5.00 7.00 3.50 (a) 5.00 5.00 (a) (b) Not applicable. Initial and ultimate medical cost trend rate for certain Medicare-eligible participants is 3.00%. 139 Other Ameren sponsors a 401(k) plan for eligible employees. The Ameren 401(k) plan covered all eligible Ameren employees at December 31, 2021. The plan allows employees to contribute a portion of their compensation in accordance with specific guidelines. Ameren matches a percentage of the employee contributions up to certain limits. The following table presents the portion of the matching contribution to the Ameren 401(k) plan attributable to each of the Ameren Companies for the years ended December 31, 2021, 2020, and 2019: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 21 16 1 38 $ $ 20 17 1 38 $ $ 19 16 — 35 2021 2020 2019 NOTE 11 – STOCK-BASED COMPENSATION The 2014 Omnibus Incentive Compensation Plan is Ameren’s long-term stock-based compensation plan for eligible employees and directors. It provides for a maximum of 8 million common shares to be available for grant to eligible employees and directors. At December 31, 2021, there were 1.8 million common shares remaining for grant. Awards may be stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance share units, cash-based awards, and other stock-based awards. Ameren used newly issued shares to fulfill its stock-based compensation obligations for 2021, 2020, and 2019, and intends to use newly issued shares to fulfill its stock-based compensation obligations for 2022. The following table summarizes Ameren’s nonvested performance share unit and restricted stock unit activity for the year ended December 31, 2021: Performance Share Units – Market Condition(a) Performance Share Units – Performance Condition(b) Restricted Stock Units Share Units Weighted-average Fair Value per Share Unit Shares Weighted-average Fair Value per Share Unit Stock Units Weighted-average Fair Value per Stock Unit Nonvested at January 1, 2021(c) . . . . . Granted . . . . . . . . . . . . . . . . . . . . . . Forfeitures . . . . . . . . . . . . . . . . . . . . Vested and undistributed(d) . . . . . . . . Vested and distributed . . . . . . . . . . . Performance share adjustment . . . . . Nonvested at December 31, 2021(e) . . 464,139 $ 266,081 (21,143) (186,792) (93,499) — 428,786 $ 73.34 87.11 80.77 77.91 62.88 — 81.81 31,896 $ 42,672 (2,449) (15,134) — (13,881) 43,104 $ 76.66 78.11 77.55 77.27 — 77.54 77.54 303,695 $ 129,723 (10,209) (87,427) (87,597) — 248,185 $ 68.52 78.17 74.88 73.13 56.38 — 75.97 (a) (b) (c) (d) (e) The exact number of shares issued pursuant to a share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the specified market conditions. Compensation cost on nonforfeited awards is recognized regardless of whether Ameren achieves the specified market conditions. The exact number of shares issued pursuant to a share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the performance goals. Compensation cost is recognized ratably over the requisite service period only for awards for which it is probable that the performance condition will be satisfied. The performance share adjustment represents the change in the probability that a performance condition will be satisfied. Does not include 366,243 market condition performance share units, 7,607 performance shares based on Ameren’s clean energy transition, and 160,034 restricted stock units that were vested and undistributed. Vested and undistributed units are awards that vest on a pro-rata basis due to attainment of retirement eligibility by certain employees, but have not yet been distributed. For vested and undistributed performance share units, the number of shares issued for retirement-eligible employees will vary depending on actual performance over the three-year performance period. Does not include 357,575 market condition performance share units, 22,739 performance shares based on Ameren’s clean energy transition, and 164,000 restricted stock units that were vested and undistributed. Performance Share Units – Market Condition A market condition performance share unit vests and entitles an employee to receive shares of Ameren common stock (plus accumulated dividends) if, at the end of the three-year performance period, certain specified market conditions have been met and if the individual remains employed by Ameren through the required vesting period. The vesting period for share units awarded extends beyond the three-year performance period to the payout date, which is approximately 38 months after the grant date. In the event of a participant’s death or retirement at age 55 or older with five years or more of service, awards vest on a pro-rata basis over the three-year performance period. The exact number of shares issued pursuant to a share unit varies from 0% to 200% of the target award, depending on actual company performance relative to the specified market conditions. The fair value of each share unit is based on Ameren’s closing common share price at December 31 of the year prior to the award year and a Monte Carlo simulation. The Monte Carlo simulation is used to estimate expected share payout based on Ameren’s TSR for a three- year performance period relative to the designated peer group beginning January 1st of the award year. The simulation can produce a 140 greater fair value for the share unit than the applicable closing common share price because it includes the weighted payout scenarios in which an increase in the share price has occurred and/or in which the payout is above 100% due to Ameren’s projected TSR performance. The significant assumptions used to calculate fair value also include a three-year risk-free rate, Ameren’s common stock volatility, and volatility for the peer group. The following table presents the fair value of each share unit along with the significant assumptions used to calculate the fair value of each share unit for the years ended December 31, 2021, 2020, and 2019: Fair value of share units awarded . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Three-year risk-free rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren’s common stock volatility(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Volatility range for the peer group(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) Based on a historical period that is equal to the remaining term of the performance period as of the grant date. Performance Share Units – Performance Condition 2021 $87.11 0.17% 2020 $82.49 1.62% 2019 $67.42 2.46% 28% 15% 26% – 36% 14% – 28% 15% – 25% 17% A performance condition share unit vests and entitles an employee to receive shares of Ameren common stock (plus accumulated dividends) if, at the end of the three-year performance period, Ameren has met the specified performance condition and if the individual remains employed by Ameren through the required vesting period. The vesting period for share units awarded extends beyond the three-year performance period to the payout date, which is approximately 38 months after the grant date. In the event of a participant’s death or retirement at age 55 or older with five years or more of service, awards vest on a pro-rata basis over the three-year performance period. The exact number of shares issued pursuant to a share unit varies from 0% to 200% of the target award, depending on actual performance conditions achieved. The specified performance condition is based on Ameren’s clean energy transition. The grant-date fair value for an individual outcome of a performance condition is determined by Ameren’s closing common share price on the grant date. Restricted Stock Units Restricted stock units vest and entitle an employee to receive shares of Ameren common stock (plus accumulated dividends) if the individual remains employed with Ameren through the payment date of the awards. Generally, in the event of a participant’s death or retirement at age 55 or older with five years or more of service, awards vest on a pro-rata basis. The payout date of the awards is approximately 38 months after the grant date. The fair value of each restricted stock unit is determined by Ameren’s closing common share price on the grant date. Stock-Based Compensation Expense The following table presents the stock-based compensation expense for the years ended December 31, 2021, 2020, and 2019: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Income tax benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stock-based compensation expense, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2021 2020 2019 5 3 14 22 6 16 $ $ 5 3 13 21 6 15 $ $ 4 3 13 20 5 15 (a) Represents compensation expense for employees of Ameren Services. These amounts are not included in the Ameren Missouri and Ameren Illinois amounts above. Ameren settled performance share units and restricted stock units of $50 million, $58 million, and $83 million for the years ended December 31, 2021, 2020, and 2019. There were no significant stock-based compensation costs capitalized during the years ended December 31, 2021, 2020, and 2019. As of December 31, 2021, total compensation cost of $35 million related to nonvested awards not yet recognized is expected to be recognized over a weighted-average period of 21 months. For the years ended December 31, 2021, 2020, and 2019, excess tax benefits associated with the settlement of stock-based compensation awards reduced income tax expense by $5 million, $8 million, and $15 million, respectively. NOTE 12 – INCOME TAXES Missouri Income Tax Rate In 2018, legislation modifying Missouri tax law was enacted to decrease the state’s corporate income tax rate from 6.25% to 4%, effective January 1, 2020. As a result, in 2018, Ameren’s and Ameren Missouri’s accumulated deferred tax balances were revalued, resulting in a net decrease of $122 million to their accumulated deferred tax liability, which was offset by a regulatory liability. Additionally, Ameren recorded an immaterial amount to income tax expense. As a result of the March 2020 MoPSC electric rate order, the effect of this tax 141 decrease was reflected in customer rates on April 1, 2020. This income tax decrease did not have a material impact on the net income of Ameren (parent) and nonregistrant subsidiaries. The following table presents the principal reasons for the difference between the effective income tax rate and the federal statutory corporate income tax rate for the years ended December 31, 2021, 2020, and 2019: Ameren Missouri Ameren Illinois Ameren 2021 Federal statutory corporate income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increases (decreases) from: Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Renewable and other tax credits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2020 Federal statutory corporate income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increases (decreases) from: Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 Federal statutory corporate income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increases (decreases) from: Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) 21 % (15) (1) (7) 3 — 1 % 21 % (16) (1) 3 — 7 % 21 % (11) (1) 5 — 14 % 21 % (3) — — 7 — 25 % 21 % (3) (1) 7 — 24 % 21 % (4) — 7 — 24 % (a) 21 % (8) — (3) 5 (1) 14 % 21 % (9) (1) 5 (1) 15 % 21 % (7) (1) 6 (1) 18 % (a) Includes credits associated with the High Prairie Renewable 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. 142 The following table presents the components of income tax expense (benefit) for the years ended December 31, 2021, 2020, and 2019: Ameren Missouri Ameren Illinois Other Ameren 2021 Current taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — — (15) $ (7) Deferred taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credits . . . . . . . . . . . . . . . . . . . . Total income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 Current taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credits . . . . . . . . . . . . . . . . . . . . Total income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2019 Current taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of excess deferred income taxes . . . . . . . . . . . . . . . . . . . . . Amortization of deferred investment tax credits . . . . . . . . . . . . . . . . . . . . Total income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 22 1 (15) 4 (1) — 11 $ (24) $ 8 24 (10) (1) — $ $ 65 23 (81) (4) 3 14 3 82 15 (75) (5) $ $ 120 59 (14) — 143 12 (6) 81 52 (15) — 34 $ 124 $ (3) $ $ 65 22 37 5 (56) (5) $ 19 11 66 29 (15) — 68 $ 110 $ (88) $ (14) 82 25 (1) — 4 $ 7 (6) 170 86 (96) (4) 157 2 5 187 57 (91) (5) 155 (4) 19 185 59 (72) (5) 182 The following table presents the accumulated deferred income tax assets and liabilities recorded as a result of temporary differences and accumulated deferred investment tax credits at December 31, 2021 and 2020: Ameren Missouri Ameren Illinois Other Ameren 2021 Accumulated deferred income taxes, net liability (asset): Plant-related . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Regulatory assets and liabilities, net . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred employee benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tax carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total net accumulated deferred income tax liabilities (assets) . . . . . . . . . . Accumulated deferred investment tax credits . . . . . . . . . . . . . . . . . . . . . . Accumulated deferred income taxes and investment tax credits . . . . . . . . $ 2020 Accumulated deferred income taxes, net liability (asset): Plant-related . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Regulatory assets and liabilities, net . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred employee benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tax carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total net accumulated deferred income tax liabilities (assets) . . . . . . . . . . Accumulated deferred investment tax credits . . . . . . . . . . . . . . . . . . . . . . Accumulated deferred income taxes and investment tax credits . . . . . . . . $ 2,188 $ 1,715 $ 226 $ (259) (52) (68) 13 1,822 30 (199) 17 (46) 71 1,558 — 1,852 $ 1,558 $ (25) (53) (84) 25 89 — 89 $ 2,112 $ 1,559 $ 205 $ (285) (58) (26) (35) 1,708 34 1,742 $ (207) 8 (6) 13 1,367 — 1,367 $ (23) (54) (65) 39 102 — 102 $ 4,129 (483) (88) (198) 109 3,469 30 3,499 3,876 (515) (104) (97) 17 3,177 34 3,211 143 The following table presents the components of accumulated deferred income tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2021 and 2020: Ameren Missouri Ameren Illinois Other Ameren 2021 Net operating loss carryforwards: Federal(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Total net operating loss carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . $ Tax credit carryforwards: Federal(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total tax credit carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 Net operating loss carryforwards: State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ Total net operating loss carryforwards Tax credit carryforwards: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total tax credit carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (a) Will not expire. (b) Will expire between 2032 and 2041. (c) Will expire between 2030 and 2041. (d) Will expire between 2022 and 2026. Uncertain Tax Positions 2 1 3 65 — 65 — — 26 — 26 $ $ $ $ $ $ $ $ $ 17 25 42 3 1 4 3 3 3 — 3 $ $ $ $ $ $ $ $ $ 15 5 20 $ $ $ 58 $ 6 64 $ 4 4 54 7 61 $ $ $ $ 34 31 65 126 7 133 7 7 83 7 90 As of December 31, 2021 and 2020, the Ameren Companies did not record any uncertain tax positions. Ameren is a part of the IRS’s compliance assurance process program, which involves real-time review of compliance with federal income tax law. State income tax returns are generally subject to examination for a period of three years after filing. The state impact of any federal changes remains subject to examination by various states for up to one year after formal notification to the states. Ameren’s federal tax returns for the 2015, 2017, 2018, 2019, and 2020 tax years are open, but, at the time of this filing, the Ameren Companies do not have material income tax issues under examination, administrative appeals, or litigation. Ameren Missouri has an uncertain tax position tracker. Under Missouri’s regulatory framework, uncertain tax positions do not reduce Ameren Missouri’s electric rate base. When an uncertain income tax position liability is resolved, the MoPSC requires, through the uncertain tax position tracker, the creation of a regulatory asset or regulatory liability to reflect the time value, with a return at the applicable WACC included in each of the electric rate orders in effect before the tax position was resolved, of the difference between the uncertain tax position liability that was excluded from rate base and the final tax liability. The resulting regulatory asset or liability will affect earnings in the year it is created. It will then be amortized over three years, beginning on the effective date of new rates established in the next electric service regulatory rate review. NOTE 13 – RELATED-PARTY TRANSACTIONS In the normal course of business, Ameren Missouri and Ameren Illinois engage in affiliate transactions. These transactions primarily consist of natural gas and power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between Ameren’s subsidiaries are reported as affiliate transactions on their individual financial statements, but those transactions are eliminated in consolidation for Ameren’s consolidated financial statements, except as noted in Software Licensing Agreement discussion below. Below are the material related-party agreements. Electric Power Supply Agreements Ameren Illinois must acquire capacity and energy sufficient to meet its obligations to customers. Ameren Illinois uses periodic RFP processes, administered by the IPA and approved by the ICC, to contract capacity and energy on behalf of its customers. Ameren Missouri participates in the RFP process and has been a winning supplier for certain periods. 144 Capacity Supply Agreements In procurement events in 2021, Ameren Missouri contracted to supply a portion of Ameren Illinois’ capacity requirements for $2 million from June 2022 through May 2023. Energy Product Agreements Based on the outcome of IPA-administered procurement events, Ameren Missouri and Ameren Illinois have entered into energy product agreements by which Ameren Missouri agreed to sell, and Ameren Illinois agreed to purchase, a set amount of MWhs at a predetermined price over a specified period of time. The following table presents the specified performance period, price, and amount of MWhs included in the agreements: IPA Procurement Event Performance Period April 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . March 2019 – May 2020 April 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 2019 – September 2020 April 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . January 2020 – December 2021 September 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . April 2020 – November 2021 September 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 2021 – November 2022 April 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . July 2022 – November 2022 September 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . January 2022 – September 2023 MWh 85,600 110,000 288,000 170,800 204,800 33,600 136,000 $ Average Price per MWh 34 32 35 29 31 34 37 Collateral Postings Under the terms of the Illinois energy product agreements entered into through RFP processes administered by the IPA, suppliers must post collateral under certain market conditions to protect Ameren Illinois in the event of nonperformance. The collateral postings are unilateral, which means that only the suppliers can be required to post collateral. Therefore, Ameren Missouri, as a winning supplier in the RFP process, may be required to post collateral. As of December 31, 2021 and 2020, there were no collateral postings required of Ameren Missouri related to the Illinois energy product agreements. Interconnection Agreements Ameren Missouri and Ameren Illinois are parties to an interconnection agreement that governs the connection of their respective transmission lines and other facilities used for the distribution of power. These agreements have no contractual expiration date, but may be terminated by either party with three years’ notice. Ameren Missouri and ATXI are parties to an interconnection agreement that governs the connection of the High Prairie Renewable Energy Center to an ATXI transmission line that allows Ameren Missouri to distribute power generated from the High Prairie Renewable Energy Center. See Note 15 – Supplemental Information for further information on the acquisition of the High Prairie Renewable Energy Center. Support Services Agreements Ameren Services provides support services to its affiliates. The costs of support services including wages, employee benefits, professional services, and other expenses, are based on, or are an allocation of, actual costs incurred. The support services agreement can be terminated at any time by the mutual agreement of Ameren Services and that affiliate or by either party with 60 days’ notice before the end of a calendar year. In addition, Ameren Missouri and Ameren Illinois provide affiliates with access to their facilities for administrative purposes and with use of other assets. The costs of the rent and facility services and other assets are based on, or are an allocation of, actual costs incurred. Ameren Missouri and Ameren Illinois also provide storm-related and miscellaneous support services to each other on an as-needed basis. At December 31, 2021, Ameren Missouri and Ameren Illinois had long-term receivables included in “Other assets” from Ameren Services of $77 million and $80 million, respectively, related to Ameren Services’ allocated portion of Ameren’s pension and postretirement benefit plans. Transmission Services Ameren Missouri and Ameren Illinois receives transmission services from ATXI for their retail load. 145 Electric Transmission Maintenance and Construction Agreements ATXI entered into separate agreements with Ameren Missouri and Ameren Illinois in which Ameren Missouri or Ameren Illinois, as applicable, may perform certain maintenance and construction services related to ATXI’s electric transmission assets. Money Pool See Note 4 – Short-term Debt and Liquidity for a discussion of affiliate borrowing arrangements. Software Licensing Agreement In September 2019, Ameren Missouri purchased a license for advanced metering infrastructure software from Ameren Illinois. The amount of the $24 million cost-based transaction price over the $5 million remaining carrying value of the software was recorded as revenue by Ameren Illinois, with $14 million of revenue recorded at Ameren Illinois Electric Distribution and $5 million recorded at Ameren Illinois Natural Gas. The revenue recorded at Ameren Illinois Electric Distribution was reflected in formula ratemaking, which resulted in no impact to net income. Per authoritative accounting guidance for sales to rate-regulated entities, the revenue recognized by Ameren Illinois was not eliminated upon consolidation by Ameren. Ameren Missouri’s cost-based investment of $24 million was included in “Property, Plant, and Equipment, Net.” Tax Allocation Agreement See Note 1 – Summary of Significant Accounting Policies for a discussion of the tax allocation agreement. The following table presents the affiliate balances related to income taxes for Ameren Missouri and Ameren Illinois as of December 31, 2021 and December 31, 2020: Income taxes payable to parent(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Income taxes receivable from parent(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — $ 27 $ 8 18 — $ 9 6 15 2021 2020 Ameren Missouri Ameren Illinois Ameren Missouri Ameren Illinois (a) (b) Included in “Accounts payable – affiliates” on the balance sheet. Included in “Accounts receivable – affiliates” on the balance sheet. Capital Contributions The following table presents cash capital contributions received from Ameren (parent) by Ameren Missouri and Ameren Illinois for the years ended December 31, 2021, 2020, and 2019: Ameren Missouri(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 207 262 $ 491 464 124 15 2021 2020 2019 (a) Includes capital contributions made as a result of the tax allocation agreement. 146 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 years ended December 31, 2021, 2020, and 2019. It is based primarily on the agreements discussed above and the money pool arrangements discussed in Note 4 – Short-term Debt and Liquidity. Agreement Income Statement Line Item Ameren Missouri Ameren Illinois Ameren Missouri power supply agreements with Ameren Illinois Ameren Missouri and Ameren Illinois rent and facility services Operating Revenues Operating Revenues Ameren Missouri and Ameren Illinois miscellaneous support services and services provided to ATXI Operating Revenues Ameren Missouri software licensing with Ameren Illinois Total Operating Revenues Ameren Illinois power supply agreements with Ameren Missouri Ameren Missouri and Ameren Illinois transmission services from ATXI Total Purchased Power Ameren Missouri and Ameren Illinois rent and facility services Ameren Services support services agreement Total Other Operations and Maintenance Expenses Money pool borrowings (advances) Operating Revenues Purchased Power Purchased Power Other Operations and Maintenance Other Operations and Maintenance (Interest Charges) Other Income, Net 2021 $ 2020 2019 2021 2020 2019 2021 2020 2019 2021 2020 2019 2021 $ 2020 2019 2021 $ 2020 2019 2021 2020 2019 2021 $ 2020 2019 2021 $ 2020 2019 2021 2020 2019 16 $ 11 3 26 26 27 (b) 3 1 (a) (a) (a) 42 $ 40 31 (a) $ (a) (a) 4 (a) (a) 4 $ (a) (a) 1 $ (b) 2 147 140 135 2021 $ 148 $ 2020 2019 2021 $ 2020 2019 140 137 (b) $ (b) (b) (a) (a) (a) 1 1 2 5 1 2 (a) (a) 19 6 2 23 16 11 3 1 2 2 17 13 5 4 4 5 137 133 127 141 137 132 (b) (b) (b) (a) (b) Not applicable. Amount less than $1 million. NOTE 14 – 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, will not have a material adverse effect on our results of operations, financial position, or liquidity. See also Note 1 – Summary of Significant Accounting Policies, Note 2 – Rate and Regulatory Matters, Note 9 – Callaway Energy Center, Note 13 – Related-party Transactions, and Note 15 – Supplemental Information in this report. 147 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. Clean Air Act regulations that apply to the electric utility industry include the NSPS, the CSAPR, the MATS, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO2, particulate matter, NOx, mercury, toxic metals, and acid gases, and CO2 emissions from new power plants. Regulations implementing the Clean Water Act govern both intake and discharges of water 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, these capital expenditures 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 our surface impoundments at Ameren Missouri’s 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 of Ameren Missouri’s energy centers. Ameren and Ameren Missouri expect that such compliance costs would be recoverable through rates, subject to MoPSC prudence review, but the timing of costs and their recovery could be subject to regulatory lag. Ameren and Ameren Missouri estimate that they will need to make capital expenditures of $125 million to $175 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 coal-fired energy centers as set forth in the 2020 IRP and as noted in the NSR and Clean Air Act litigation discussed below, Ameren Missouri’s current plan for compliance with existing air emission regulations includes natural gas-fired energy center retirements as discussed below in Illinois Emission Standards, 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 to the effluent limitation guidelines and the CCR Rule, which could ultimately result in the revision of all or part of such rules. Additionally, Ameren Missouri’s wind generation facilities may be subject to operating restrictions to limit the impact on protected species. From April 2021 through October 2021, Ameren Missouri's High Prairie Renewable Energy Center curtailed nighttime operations to limit impacts on protected species. Ameren Missouri resumed nighttime operations in November 2021 as the critical biological season had ended. Seasonal nighttime curtailment will begin again in April 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. Clean Air Act Federal and state laws, including CSAPR, regulate emissions of SO2 and NOx 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 2017. Additional emission reduction requirements may apply in subsequent years. 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. 148 CO2 Emissions Standards The EPA’s Affordable Clean Energy Rule repealed the Clean Power Plan and replaced it with a new rule that established emission guidelines for states to follow in developing plans to limit CO2 emissions and identified certain efficiency measures as the best system of emission reduction for coal-fired electric generating units. In January 2021, the United States Court of Appeals for the District of Columbia Circuit vacated the Affordable Clean Energy Rule, and ruled that the EPA had the discretion to consider emission reduction measures that include efficiency measures and generation shifting to lower carbon emissions. The United States Supreme Court agreed to review the court of appeals’ ruling and oral arguments will occur in February 2022 with a decision expected by mid-2022. A decision by the United States Supreme Court could impact the EPA’s development of new regulations to address carbon emissions from coal- and natural gas-fired electric generating units. At this time, Ameren Missouri cannot predict the outcome of the legal challenge or future rulemakings. As such, any impact on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri is uncertain. NSR and Clean Air Act Litigation In January 2011, the United States Department of Justice, on behalf of the EPA, filed a complaint against Ameren Missouri in the United States District Court for the Eastern District of Missouri alleging that in performing projects at its coal-fired Rush Island Energy Center in 2007 and 2010, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. In January 2017, the district court issued a liability ruling against Ameren Missouri and, in September 2019, entered a remedy order that required Ameren Missouri to install a flue gas desulfurization system at the Rush Island Energy Center and a dry sorbent injection system at the Labadie Energy Center. Ameren Missouri appealed both the liability and remedy orders and, in August 2021, the United States Court of Appeals for the Eighth Circuit issued a decision that affirmed the liability ruling and the district court’s remedy order as it related to the installation of a flue gas desulfurization system at the Rush Island Energy Center, but reversed the order as it related to the installation of a dry sorbent injection system at the Labadie Energy Center. In November 2021, the court of appeals issued an order denying requests for 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 has determined not to further appeal the court rulings and, in December 2021, filed a motion with the district court to modify the remedy order to allow the retirement of the Rush Island Energy Center in advance of its previously expected useful life in lieu of installing a flue gas desulfurization system. The district court is under no deadline to issue a ruling revising the remedy order. In January 2022, the MISO completed a preliminary assessment regarding potential impacts of the retirement to the regional electric power system, which indicated transmission upgrades and voltage support would be needed in advance of the retirement to address reliability concerns. In February 2022, Ameren Missouri expects to formally notify the MISO of its intent to retire the Rush Island Energy Center. Upon receipt of the formal notification, the MISO will conduct a final reliability assessment. The MISO must also separately approve the specific upgrades and transmission support required to address reliability concerns noted in the assessment. Related to this matter, in February 2022, the MoPSC issued an order directing the MoPSC staff to review the planned accelerated retirement of the Rush Island Energy Center. See Note 2 – Rate and Regulatory Matters for additional information. In connection with the planned accelerated retirement of the Rush Island Energy Center, Ameren Missouri expects to seek approval from the MoPSC to finance the costs associated with the retirement, including the remaining unrecovered net plant balance associated with the facility, through the issuance of securitized utility tariff bonds pursuant to the Missouri securitization statute that became effective in August 2021. As of December 31, 2021, 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 $0.4 billion. See Note 1 – Summary of Significant Accounting Policies for additional information regarding plant to be abandoned, net. In addition, Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect 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 of this matter; however, such resolution could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri. Clean Water Act The EPA’s regulations implementing Section 316(b) of the Clean Water Act require power plant operators to evaluate cooling water intake structures and identify measures for reducing the number of aquatic organisms impinged on a power plant’s cooling water intake screens or entrained through the plant’s cooling water system. All of Ameren Missouri’s coal-fired and nuclear energy centers are subject to the cooling water intake structures rule. Requirements of the rule are implemented by state regulators through the permit renewal process of each power plant’s water discharge permit, which is expected to be completed by 2023 for Ameren 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 149 handling systems and in 2020 completed construction of wastewater 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 EPA’s CCR Rule establishes requirements for the management and disposal of CCR from coal-fired power plants and will result in the closure of surface impoundments at Ameren Missouri’s energy centers. Ameren Missouri completed the closure of all surface impoundments at two of its facilities in 2021, and has made significant progress by closing several impoundments at its other two facilities. Ameren Missouri plans to complete the closures of the remaining surface impoundments in 2023. In January 2022, Ameren Missouri received notice of a proposed determination by the EPA that it has rejected Ameren Missouri’s requests to extend the timeline for operating certain impoundments located at the Sioux and Meramec energy centers. Compliance with the CCR Rule’s requirements for closure of the impoundments would be required 135 days after the EPA issues a final determination, which Ameren Missouri expects to be issued in the spring of 2022. 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 is in place. Ameren Missouri plans to retire the Meramec Energy Center in 2022, and is accelerating its construction plans to build a CCR Rule-compliant impoundment at the Sioux Energy Center to allow for continued operations. Additionally, Ameren Missouri is seeking a reliability determination from the MISO, which, if granted, would extend the deadline to comply with the requirement to close the impoundments and allow the energy centers to operate. 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 $76 million recorded on their respective balance sheets as of December 31, 2021, 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 December 31, 2021, Ameren Illinois has remediated the majority of the 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 December 31, 2021, Ameren Illinois estimated the remaining obligation related to these former MGP sites at $71 million to $125 million. Ameren and Ameren Illinois recorded a liability of $71 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. Illinois Emission Standards The IETL established emission standards that became effective in September 2021. Ameren Missouri's natural gas-fired energy centers in Illinois will be 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, which could limit the operations of Ameren Missouri's five natural gas-fired energy centers located in the state of Illinois, and will result in the closure of one or more energy centers earlier than anticipated. 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 is reviewing the emission standards and the effect they may have on its generation strategy, including any increases in capital expenditures or operating costs, and changes to the useful lives of the five natural gas-fired energy centers. Ameren Missouri expects to file an update to the 2020 IRP with the MoPSC in the first half of 2022 to reflect, among other things, the impact of these new emissions standards. 150 NOTE 15 – 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 as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Ameren Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 8 $ — $ Restricted cash included in “Other current assets” . . . . . . . . . . . . . . . . . . . . . . . . . . . . Restricted cash included in “Other assets” . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Restricted cash included in “Nuclear decommissioning trust fund” . . . . . . . . . . . . . . . . . 16 127 4 4 — 4 — 6 127 — $ 139 $ 136 $ 17 141 4 5 — 4 Total cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 155 $ 8 $ 133 $ 301 $ 145 $ — 6 141 — 147 Restricted cash included in “Other current assets” primarily represents funds held by an irrevocable Voluntary Employee Beneficiary Association (VEBA) trust, which provides health care benefits for active employees. Restricted cash included in “Other assets” on Ameren’s and Ameren Illinois’ balance sheets primarily represents amounts collected under a cost recovery rider restricted for use in the procurement of renewable energy credits and amounts in a trust fund restricted for the use of funding certain asbestos-related claims. Accounts Receivable “Accounts receivable – trade” on Ameren’s and Ameren Illinois’ balance sheets include certain receivables purchased at a discount from alternative retail electric suppliers that elect to participate in the utility consolidated billing program. At December 31, 2021 and 2020, “Other current liabilities” on Ameren’s and Ameren Illinois’ balance sheets included payables for purchased receivables of $27 million and $28 million, respectively. The following table provides a reconciliation of the beginning and ending amount of the allowance for doubtful accounts for the years ended December 31, 2021 and 2020: Beginning of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Bad debt expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net write-offs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . End of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 16 5 (8) 13 Ameren Missouri December 31, 2021 December 31, 2020 Ameren Illinois(a) $ 34 (b) 4 (22) 16 $ Ameren Ameren Missouri Ameren Illinois(a) Ameren $ $ 50 9 (30) 29 $ $ 7 $ 15 (6) 16 $ 10 $ 33 (9) 34 $ 17 48 (15) 50 (a) (b) Ameren Illinois has rate-adjustment mechanisms that allow it to recover the difference between its actual net bad debt write-offs under GAAP, including those associated with receivables purchased from alternative retail electric suppliers, and the amount of net bad debt write-offs included in its base rates. In 2021, Ameren Illinois’ bad debt expense was reduced as a result of incremental state funding received for customer bill assistance. The incremental state funding granted relief to low-income customers at risk of service disconnection resulting from the impacts of the COVID-19 pandemic. Net write-offs increased for the year ended December 31, 2021 due to the resumption of disconnection activities for nonpayment. See Note 2 – Rate and Regulatory Matters for additional information. Inventories The following table presents the components of inventories for each of the Ameren Companies at December 31, 2021 and 2020: December 31, 2021 December 31, 2020 (a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Fuel Natural gas stored underground . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Materials, supplies, and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total inventories . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 118 $ 9 292 419 $ — $ 90 83 173 $ 118 99 375 592 Ameren Missouri Ameren Illinois Ameren (a) Consists of coal, oil, and propane. 151 Ameren Missouri $ 115 $ 5 266 386 $ $ Ameren Illinois Ameren — $ 52 83 135 $ 115 57 349 521 Property, Plant, and Equipment In January 2021, Ameren Missouri acquired a 300-MW wind generation project located in northwestern Missouri. As of June 30, 2021, Ameren Missouri had placed the project in service as the Atchison Renewable Energy Center. The purchase price of the energy center was approximately $500 million, including an immaterial amount of transaction costs. In December 2020, Ameren Missouri acquired a 400-MW wind generation project located in northeastern Missouri for approximately $615 million, and placed the assets in service as the High Prairie Renewable Energy Center. The purchase price included $564 million of cash, a deferred purchase price obligation withheld as credit support in relation to certain potential claims, contingent consideration, and transaction costs. Both renewable energy centers support Ameren Missouri’s compliance with the Missouri renewable energy standard. Asset Retirement Obligations The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the years ended December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Beginning balance at January 1 . . . . . . . . . . . . . . . . . . . . . . . . . $ Liabilities incurred . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities settled . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accretion(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in estimates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31 . . . . . . . . . . . . . . . . . . . . . . . . . $ (c) 751 18 (36) 31 (4) (e) (g) 760 — (1) — — 4 $ $ (a) 5 $ (b) (c) 756 18 (37) 31 (4) (e) $ $ (c) 687 36 (58) 29 57 (f) (a) $ (b)(g) 764 $ 751 $ 4 — — 1 — 5 $ 691 36 (58) 30 57 (a) $ 756 (c) (f) (b) (a) (b) (c) (d) (e) (f) (g) Included in “Other deferred credits and liabilities” on the balance sheet. Balance included $7 million and $60 million in “Other current liabilities” on the balance sheet as of December 31, 2021 and 2020, respectively. Ameren Missouri recorded AROs related to the decommissioning of the Atchison Renewable and High Prairie Renewable energy centers in 2021 and 2020, respectively. Accretion expense attributable to Ameren Missouri and Ameren Illinois was recorded as a decrease to regulatory liabilities and an increase to regulatory assets, respectively. Ameren Missouri changed its fair value estimate primarily due to a decrease in the cost estimate for closure of certain CCR storage facilities, partially offset by an increase due to the planned accelerated retirement of the Rush Island Energy Center. Ameren Missouri changed its fair value estimate primarily due to an update to the decommissioning of the Callaway Energy Center to reflect the cost study and funding analysis filed with the MoPSC in November 2020 and an increase in the cost estimate for closure of certain CCR storage facilities. The balance as of December 31, 2021, included an ARO related to the decommissioning of the Callaway Enter Center of $574 million. Noncontrolling Interests As of December 31, 2021 and 2020, Ameren’s noncontrolling interests included the preferred stock of Ameren Missouri and Ameren Illinois. Deferred Compensation As of December 31, 2021, and 2020, the present value of benefits to be paid for deferred compensation obligations was $91 million and $90 million, respectively, which was primarily reflected in “Other deferred credits and liabilities” on Ameren’s consolidated balance sheet. 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 years ended December 31, 2021, 2020, and 2019: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 150 125 275 $ $ 139 115 254 $ $ 147 117 264 2021 2020 2019 152 Allowance for Funds Used During Construction The following table presents the average rate that was applied to eligible construction work in progress and the amounts of allowance for funds used during construction capitalized in 2021, 2020, and 2019: 2021 2020 2019 Average rate: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 % 5 % 5 % 5 % 6 % 5 % Ameren: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Allowance for borrowed funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Missouri: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Allowance for borrowed funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Ameren Illinois: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Allowance for borrowed funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 43 17 60 26 10 36 17 7 24 $ $ $ $ $ $ 32 16 48 19 10 29 13 6 19 $ $ $ $ $ $ 28 20 48 19 12 31 9 8 17 Earnings per Share Earnings per basic and diluted share are computed by dividing “Net Income Attributable to Ameren Common Shareholders” by the weighted-average number of basic and diluted common shares outstanding, respectively, during the applicable period. The weighted-average shares outstanding for earnings per diluted share includes the incremental effects resulting from performance share units, restricted stock units, and forward sale agreements relating to common stock when the impact would be dilutive, as calculated using the treasury stock method. For information regarding performance share units and restricted stock units, see Note 11 – Stock-based Compensation. For information regarding forward sale agreements, see Note 5 – Long-term Debt and Equity Financings. The following table reconciles the weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding for the years ended December 31, 2021, 2020, and 2019: Weighted-average Common Shares Outstanding – Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Assumed settlement of performance share units and restricted stock units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Dilutive effect of forward sale agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Weighted-average Common Shares Outstanding – Diluted(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2021 2020 2019 256.3 1.3 — 257.6 247.0 1.2 0.5 248.7 245.6 1.4 0.1 247.1 (a) There was an immaterial number of anti-dilutive securities excluded from the earnings per diluted share calculations for the year ended December 31, 2021. There were no potentially dilutive securities excluded from the earnings per diluted share calculations for the years ended December 31, 2020 and 2019. 153 Supplemental Cash Flow Information The following table provides noncash financing and investing activity excluded from the statements of cash flows for the years ended December 31, 2021, 2020, and 2019: Investing Accrued capital expenditures, including wind generation expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued nuclear fuel expenditures . . . . . . . . . . . . . . . . . . . . . . . Net realized and unrealized gain – nuclear decommissioning trust fund . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Exchange of bond investments for the extinguishment of senior unsecured notes(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Financing Issuance of common stock for stock-based compensation . . . . . . $ Exchange of bond investments for the extinguishment of senior unsecured notes(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . December 31, 2021 December 31, 2020 December 31, 2019 Ameren Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois $ 508 $ 285 $ 215 $ 446 $ 229 $ 218 $ 333 $ 140 $ 163 16 163 16 163 — — 33 $ — $ — — — — — — — — 116 — 116 — — $ 38 $ — $ — — — — — — — 19 143 17 19 143 — — — 17 $ 54 $ — $ — (17) — (17) (a) In 2006, Ameren Illinois purchased all $17 million of the 1993 Series B-1 bonds due 2028 issued by the Illinois Finance Authority on behalf of Ameren Illinois pursuant to a mandatory tender. Ameren Illinois’ 1993 Series B-1 senior unsecured notes due 2028 were not extinguished and remained as “Long-term debt, net” on Ameren’s and Ameren Illinois’ balance sheets. In September 2019, Ameren Illinois exchanged its bond investments for the extinguishment of its senior unsecured notes. NOTE 16 – SEGMENT INFORMATION Ameren has four segments: Ameren Missouri, Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Transmission. The Ameren Missouri segment includes all of the operations of Ameren Missouri. Ameren Illinois Electric Distribution consists of the electric distribution business of Ameren Illinois. Ameren Illinois Natural Gas consists of the natural gas business of Ameren Illinois. Ameren Transmission primarily consists of the aggregated electric transmission businesses of Ameren Illinois and ATXI. The category called Other primarily includes Ameren (parent) activities and Ameren Services. Ameren Missouri has one segment. Ameren Illinois has three segments: Ameren Illinois Electric Distribution, Ameren Illinois Natural Gas, and Ameren Illinois Transmission. See Note 1 – Summary of Significant Accounting Policies for additional information regarding the operations of Ameren Missouri, Ameren Illinois, and ATXI. Segment operating revenues and a majority of operating expenses are directly recognized and incurred by Ameren Illinois to each Ameren Illinois segment. Common operating expenses, miscellaneous income and expenses, interest charges, and income tax expense are allocated by Ameren Illinois to each Ameren Illinois segment based on certain factors, which primarily relate to the nature of the cost. Additionally, Ameren Illinois Transmission earns revenue from transmission service provided to Ameren Illinois Electric Distribution, other retail electric suppliers, and wholesale customers. The transmission expense for Illinois customers who have elected to purchase their power from Ameren Illinois is recovered through a cost recovery mechanism with no net effect on Ameren Illinois Electric Distribution earnings, as costs are offset by corresponding revenues. Transmission revenues from these transactions are reflected in Ameren Transmission’s and Ameren Illinois Transmission’s operating revenues. An intersegment elimination at Ameren and Ameren Illinois occurs to eliminate these transmission revenues and expenses. 154 The following tables present information about the reported revenue and specified items reflected in net income attributable to common shareholders and capital expenditures by segment at Ameren and Ameren Illinois for the years ended December 31, 2021, 2020, and 2019. Ameren, Ameren Missouri, and Ameren Illinois management review segment capital expenditure information rather than any individual or total asset amount. Ameren 2021 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Other Intersegment Eliminations Ameren 3,311 $ 1,635 $ 957 $ 3,069 $ 1,496 $ 760 $ 469 $ Capital expenditures . . . . . . . . . . . . . . . . 2,015 (b) External revenues . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . Net income (loss) attributable to Ameren common shareholders . . . . . . . . . . . . . . 2020 External revenues . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . Net income (loss) attributable to Ameren common shareholders . . . . . . . . . . . . . . 42 632 26 137 3 518 40 604 26 190 34 436 4 309 1 74 53 165 579 — 90 — 42 39 108 278 $ (a) 491 71 111 — 83 82 230 616 2 288 2 72 42 143 543 — 81 — 41 36 99 301 (a) 54 98 1 78 78 216 716 Capital expenditures . . . . . . . . . . . . . . . . 1,666 (b) 2019 External revenues . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . Net income (loss) attributable to Ameren common shareholders . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . 3,212 $ 1,487 $ 791 $ 401 $ 31 556 26 178 68 426 1,076 17 273 6 71 45 146 518 6 78 — 38 30 84 318 (a) 63 84 1 74 64 185 528 — — 4 3 50 (20) (31) 4 — — 4 4 42 (35) (23) 5 — — 4 5 25 (25) (13) 3 $ — $ 6,394 (117) — (3) (3) — — (13) — (96) — (4) (4) — — 2 — (98) — (5) (5) — — (32) (d) — 1,146 27 383 157 990 3,479 (b) $ 5,794 — 1,075 29 419 155 871 3,233 (b) $ 5,891 (c) 19 995 33 381 182 828 2,411 $ $ (a) (b) (c) (d) Ameren Transmission interest charges include an allocation of financing costs from Ameren (parent). Includes $525 million and $564 million at Ameren and Ameren Missouri for wind generation expenditures for the year ended December 31, 2021 and 2020, respectively. Intersegment revenues at Ameren include $14 million and $5 million of revenue from Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the year ended December 31, 2019, for a software licensing agreement with Ameren Missouri. Under authoritative accounting guidance for rate-regulated entities, the revenue recognized by Ameren Illinois was not eliminated upon consolidation. See Note 13 – Related-party Transactions for additional information. Intersegment capital expenditure eliminations include $24 million of eliminations for the year ended December 31, 2019, for a software licensing agreement between Ameren Illinois and Ameren Missouri. See Note 13 – Related-party Transactions for additional information. 155 Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois 2021 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income available to common shareholder . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2020 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income available to common shareholder . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income available to common shareholder . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,639 $ 957 $ 299 $ — 309 1 74 53 165 579 — 90 — 42 39 108 278 66 73 — 48 51 152 575 1,498 $ 760 $ 277 $ — 288 2 72 42 143 543 — 81 — 41 36 99 301 52 65 1 42 46 137 603 1,504 $ 797 $ 226 $ — 273 6 71 45 146 518 — 78 — 38 30 84 318 62 55 — 38 35 113 372 — (66) — — — — — — — (52) — — — — — — — (62) — — — — — — $ 2,895 — 472 1 164 143 425 1,432 $ 2,535 — 434 3 155 124 379 1,447 $ 2,527 — 406 6 147 110 343 1,208 156 The following tables present disaggregated revenues by segment at Ameren and Ameren Illinois for the years ended December 31, 2021, 2020, and 2019. 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 2021 Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenues . . . . . . . . . . . $ Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total gas revenues . . . . . . . . . . . . . . $ Total revenues(a) . . . . . . . . . . . . . . . $ 2020 Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenues . . . . . . . . . . . $ Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total gas revenues . . . . . . . . . . . . . . $ Total revenues(a) . . . . . . . . . . . . . . . $ 2019 Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenues . . . . . . . . . . . $ Residential . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . Total gas revenues . . . . . . . . . . . . . . $ Total revenues(a) . . . . . . . . . . . . . . . $ Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Intersegment Eliminations Ameren 1,445 1,126 280 361 3,212 79 34 4 24 141 3,353 1,373 1,025 261 325 2,984 76 29 4 16 125 3,109 1,403 1,157 278 271 3,109 81 34 4 15 134 3,243 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 933 545 135 26 1,639 — — — — — 1,639 867 486 124 21 1,498 — — — — — 1,498 848 497 127 (b) 32 1,504 — — — — — 1,504 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ — — — — — 657 172 35 93 957 957 — — — — — 541 136 14 69 760 760 — — — — — 570 154 13 60 797 797 (b) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ — — — 562 562 — — — — — 562 — — — 523 523 — — — — — 523 — — — 464 464 — — — — — 464 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ — — — (116) (116) — — — (1) (1) (117) — — — (94) (94) — — — (2) (2) (96) — — — (96) (96) — — — (2) (2) (98) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 2,378 1,671 415 833 5,297 736 206 39 116 1,097 6,394 2,240 1,511 385 775 4,911 617 165 18 83 883 5,794 2,251 1,654 405 671 4,981 651 188 17 73 929 5,910 (a) The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the years ended December 31, 2021, 2020, and 2019: 157 Ameren Missouri Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Transmission Ameren 2021 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . 2020 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . 2019 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . $ $ $ (16) 56 (a) (14) 25 35 19 $ $ $ 77 10 (20) 8 (74) 7 $ $ $ 5 2 20 2 — 2 $ $ $ 11 — 50 1 (31) — (a) 77 68 36 36 (70) 28 (a) Includes insurance recoveries related to lost sales associated with the Callaway Energy Center maintenance outage. See Note 9 – Callaway Energy Center for additional information. (b) Includes $14 million and $5 million for Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the year ended December 31, 2019, for a software licensing agreement with Ameren Missouri. See Note 13 – Related-party Transactions for additional information. Ameren Illinois Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Intersegment Eliminations Ameren Illinois 2021 Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total revenues(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total revenues(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2019 Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total revenues(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 933 545 135 26 1,639 867 486 124 21 1,498 848 497 127 32 1,504 (b) $ $ $ $ $ $ 657 172 35 93 957 541 136 14 69 760 570 154 13 60 797 (b) $ $ $ $ $ $ — — — 365 365 — — — 329 329 — — — 288 288 $ $ $ $ $ $ — — — (66) (66) — — — (52) (52) — — — (62) (62) $ $ $ $ $ $ 1,590 717 170 418 2,895 1,408 622 138 367 2,535 1,418 651 140 318 2,527 (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 for the years ended December 31, 2021, 2020, and 2019: Ameren Illinois Electric Distribution Ameren Illinois Natural Gas Ameren Illinois Transmission Ameren Illinois 2021 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . 2020 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . 2019 Revenues from alternative revenue programs . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other revenues not from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ 77 10 (20) 8 (74) 7 $ $ $ 5 2 20 2 — 2 $ $ $ 9 — 42 — (33) — 91 12 42 10 (107) 9 (b) Includes $14 million and $5 million for Ameren Illinois Electric Distribution and Ameren Illinois Natural Gas, respectively, for the year ended December 31, 2019, for a software licensing agreement with Ameren Missouri. See Note 13 – Related-party Transactions for additional information. 158 ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. ITEM 9A. CONTROLS AND PROCEDURES (a) Evaluation of Disclosure Controls and Procedures As of December 31, 2021, evaluations were performed under the supervision and with the participation of management, including the principal executive officer and the principal financial officer of each of the Ameren Companies, of the effectiveness of the design and operation of such registrant’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act). Based on those evaluations, as of December 31, 2021, the principal executive officer and the principal financial officer of each of the Ameren Companies concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in such registrant’s reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to its management, including its principal executive and principal financial officers, to allow timely decisions regarding required disclosure. (b) Management’s Report on Internal Control over Financial Reporting Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Under the supervision of and with the participation of management, including the principal executive officer and the principal financial officer, an evaluation was conducted of the effectiveness of each of the Ameren Companies’ internal control over financial reporting based on the framework in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). After making that evaluation, management concluded that each of the Ameren Companies’ internal control over financial reporting was effective as of December 31, 2021. The effectiveness of Ameren’s internal control over financial reporting as of December 31, 2021, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in its report herein under Part II, Item 8. This annual report does not include an attestation report of Ameren Missouri’s or Ameren Illinois’ (the Subsidiary Registrants) independent registered public accounting firm regarding internal control over financial reporting. Management’s report for each of the Subsidiary Registrants is not subject to attestation by an independent registered public accounting firm. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness into future periods are subject to the risk that internal controls might become inadequate because of changes in conditions, and to the risk that the degree of compliance with the policies or procedures might deteriorate. (c) Change in Internal Control There has been no change in 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, their internal control over financial reporting. ITEM 9B. OTHER INFORMATION The Ameren Companies have no information reportable under this item that was required to be disclosed in a report on SEC Form 8-K during the fourth quarter of 2021 that has not previously been reported. ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS Not Applicable. ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE PART III Information required by Items 401, 405, 406 and 407(c)(3),(d)(4) and (d)(5) of SEC Regulation S-K for Ameren will be included in its definitive proxy statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14A; it is incorporated herein by reference. Information required by these SEC Regulation S-K items for Ameren Missouri and Ameren Illinois will be included in each company’s definitive information statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14C; it is incorporated herein by reference. Specifically, reference is made to the following sections of Ameren’s definitive proxy statement and to each of Ameren Missouri’s and Ameren Illinois’ definitive information statements: “Information Concerning Nominees to the Board of Directors,” “Section 16(a) Reports,” “Corporate Governance” and “Board Structure.” 159 Information concerning executive officers of the Ameren Companies required by Item 401 of SEC Regulation S-K is reported under a separate caption entitled “Information about our Executive Officers” in Part I of this report. Ameren Missouri and Ameren Illinois do not have separately designated standing audit committees, but instead use Ameren’s Audit and Risk Committee to perform such committee functions for their boards of directors. These companies do not have securities listed on the NYSE and therefore are not subject to the NYSE listing standards. J. Edward Coleman serves as chairman of Ameren’s Audit and Risk Committee and Catherine S. Brune, Ward H. Dickson, Noelle K. Eder, and Leo S. Mackay, Jr. serve as members. The board of directors of Ameren has determined that J. Edward Coleman and Ward H. Dickson each qualify as an audit committee financial expert and that each is “independent” as that term is used in SEC Regulation 14A. Also, on the same basis as reported above, the boards of directors of Ameren Missouri and Ameren Illinois use the Nominating and Corporate Governance Committee of Ameren’s board of directors to perform such committee functions. This Committee is responsible for the nomination of directors and for corporate governance practices. Ameren’s Nominating and Corporate Governance Committee will consider director nominations from shareholders in accordance with its Policy Regarding Nominations of Directors, which can be found on Ameren’s website: www.amereninvestors.com. To encourage ethical conduct in its financial management and reporting, Ameren has adopted a code of ethics that applies to the directors, officers, and employees of the Ameren Companies. Ameren has also adopted a supplemental code of ethics that applies to the principal executive officer, the president, the principal financial officer, the principal accounting officer, the controller, and the treasurer of the Ameren Companies. The Ameren Companies make available free of charge through Ameren’s website (www.amereninvestors.com) the code of ethics and the supplemental code of ethics. Any amendment to the code of ethics or the supplemental code of ethics and any waiver from a provision of the code of ethics or the supplemental code of ethics as it relates to the principal executive officer, the president, the principal financial officer, the principal accounting officer, the controller, or the treasurer of each of the Ameren Companies will be posted on Ameren’s website within four business days following the date of the amendment or waiver. ITEM 11. EXECUTIVE COMPENSATION Information required by Items 402 and 407(e)(4) and (e)(5) of SEC Regulation S-K for Ameren will be included in its definitive proxy statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14A; it is incorporated herein by reference. Information required by these SEC Regulation S-K items for Ameren Missouri and Ameren Illinois will be included in each company’s definitive information statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14C; it is incorporated herein by reference. Specifically, reference is made to the following sections of Ameren’s definitive proxy statement and to each of Ameren Missouri’s and Ameren Illinois’ definitive information statements: “Executive Compensation Matters” and “Human Resources Committee Interlocks and Insider Participation.” ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS Equity Compensation Plan Information The following table presents information as of December 31, 2021, with respect to the shares of Ameren’s common stock that may be issued under its existing equity compensation plans: Plan Category Equity compensation plans approved by security holders(b) . . . . . . . . . . . . Equity compensation plans not approved by security holders . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Column A Number of Securities To Be Issued Upon Exercise of Outstanding Options, Warrants and Rights(a) Column B Weighted-Average Exercise Price of Outstanding Options, Warrants and Rights Column C Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (excluding securities reflected in Column A) 1,442,122 — 1,442,122 (c) — (c) 1,753,758 — 1,753,758 (a) Of the securities to be issued, 913,649 of the securities represent the target number of outstanding performance share units (PSUs) and 433,248 of the securities represent the number of outstanding restricted stock units (RSUs), both including accrued and reinvested dividends. The actual number of shares issued in respect of the PSUs will vary from 0% to 200% of the target level, depending upon the achievement of TSR objectives or performance goals established for such awards. For additional information about the PSUs and RSUs, including payout calculations, see “Compensation Discussion and Analysis – Long-Term Incentive Compensation” in Ameren’s definitive proxy statement for its 2022 annual meeting of shareholders, which will be filed pursuant to SEC Regulation 14A. The remaining 95,225 of the securities represent shares that may be issued to satisfy obligations under the Ameren Corporation Deferred Compensation Plan for Members of the Board of Directors. Consists of the 2014 Omnibus Incentive Compensation Plan. No cash consideration is received when shares are distributed for earned PSUs, RSUs, and director awards. Accordingly, there is no weighted-average exercise price. (b) (c) Ameren Missouri and Ameren Illinois do not have separate equity compensation plans. 160 Security Ownership of Certain Beneficial Owners and Management The information required by Item 403 of SEC Regulation S-K for Ameren will be included in its definitive proxy statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14A; it is incorporated herein by reference. Information required by this SEC Regulation S-K item for Ameren Missouri and Ameren Illinois will be included in each company’s definitive information statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14C; it is incorporated herein by reference. Specifically, reference is made to the following section of Ameren’s definitive proxy statement and each of Ameren Missouri’s and Ameren Illinois’ definitive information statement: “Security Ownership.” ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE Information required by Items 404 and 407(a) of SEC Regulation S-K for Ameren will be included in its definitive proxy statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14A; it is incorporated herein by reference. Information required by these SEC Regulation S-K items for Ameren Missouri and Ameren Illinois will be included in each company’s definitive information statement for its 2022 annual meeting of shareholders filed pursuant to SEC Regulation 14C; it is incorporated herein by reference. Specifically, reference is made to the following sections of Ameren’s definitive proxy statement and to each of Ameren Missouri’s and Ameren Illinois’ definitive information statements: “Related Person Transactions Policy” and “Director Independence.” ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES Information required by Item 9(e) of SEC Schedule 14A for the Ameren Companies will be included in the definitive proxy statement of Ameren and the definitive information statements of Ameren Missouri and Ameren Illinois for their 2022 annual meetings of shareholders filed pursuant to SEC Regulations 14A and 14C, respectively; it is incorporated herein by reference. Specifically, reference is made to the following section of Ameren’s definitive proxy statement and each of Ameren Missouri’s and Ameren Illinois’ definitive information statement: “Selection of Independent Registered Public Accounting Firm.” 161 ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES PART IV (a)(1) Financial Statements Ameren Report of Independent Registered Public Accounting Firm – Page No. (PricewaterhouseCoopers LLP’s Public Company Accounting Oversight Board ID 238) . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Income and Comprehensive Income – Years Ended December 31, 2021, 2020, and 2019 . . . . . . Consolidated Balance Sheet – December 31, 2021 and 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Cash Flows – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Shareholders’ Equity – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . Ameren Missouri Report of Independent Registered Public Accounting Firm – (PricewaterhouseCoopers LLP’s Public Company Accounting Oversight Board ID 238) . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Income – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Balance Sheet – December 31, 2021 and 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Cash Flows – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Shareholders’ Equity – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Report of Independent Registered Public Accounting Firm – (PricewaterhouseCoopers LLP’s Public Company Accounting Oversight Board ID 238) . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Income – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Balance Sheet – December 31, 2021 and 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Cash Flows – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Shareholders’ Equity – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . (a)(2) Financial Statement Schedules Schedule I Condensed Financial Information of Parent – Ameren: Condensed Statement of Income and Comprehensive Income – Years Ended December 31, 2021, 2020, and 2019 . . . . Condensed Balance Sheet – December 31, 2021 and 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Condensed Statement of Cash Flows – Years Ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . . Schedule II Ameren Valuation and Qualifying Accounts for the years ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . Ameren Missouri Valuation and Qualifying Accounts for the years ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Valuation and Qualifying Accounts for the years ended December 31, 2021, 2020, and 2019 . . . . . . . . . . . . . . . . . . . . . Schedule I and II should be read in conjunction with the aforementioned financial statements. Certain schedules have been omitted because they are not applicable or because the required data is shown in the aforementioned financial statements. (a)(3) (b) Exhibits – reference is made to the Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80 86 87 88 89 82 90 91 92 93 84 94 95 96 97 163 164 165 167 167 167 168 168 162 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED STATEMENT OF INCOME AND COMPREHENSIVE INCOME For the Years Ended December 31, 2021, 2020, and 2019 (In millions) 2021 2020 2019 Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Operating expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — 13 (13) Equity in earnings of subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,039 Interest income from affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total other expense, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income tax benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net Income Attributable to Ameren Common Shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Net Income Attributable to Ameren Common Shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Other Comprehensive Income, Net of Taxes: 3 — (64) 25 990 990 $ $ Pension and other postretirement benefit plan activity, net of income taxes of $4, $5, and $1, respectively . . . . . . . . . . . . 14 $ $ $ — 12 (12) 908 4 (8) (57) 36 871 871 16 Comprehensive Income Attributable to Ameren Common Shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,004 $ 887 $ — 15 (15) 850 5 (2) (39) 29 828 828 5 833 163 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED BALANCE SHEET (In millions, except per share amounts) Assets: Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Advances to money pool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts receivable – affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous accounts and notes receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note receivable – ATXI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated deferred income taxes, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Liabilities and Shareholders’ Equity: Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Taxes accrued . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts payable – affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and other postretirement benefits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commitments and Contingencies (Note 5) Shareholders’ Equity: Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 257.7 and 253.3, respectively . . . . Other paid-in capital, principally premium on common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total shareholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total liabilities and shareholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ December 31, 2021 December 31, 2020 $ $ $ — 108 30 11 4 153 12,281 35 65 184 12,718 277 7 53 38 375 2,533 24 86 3,018 3 6,502 3,182 13 9,700 12,718 $ — 16 12 15 4 47 10,872 75 42 167 11,203 490 — 41 34 565 1,588 27 85 2,265 3 6,179 2,757 (1) 8,938 11,203 164 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED STATEMENT OF CASH FLOWS For the Years Ended December 31, 2021, 2020, and 2019 (In millions) Net cash flows provided by operating activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Cash flows from investing activities: 2021 2020 2019 79 $ 147 $ 491 Money pool advances, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Notes receivable – ATXI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net cash flows used in investing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash flows from financing activities: Dividends on common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Short-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Money pool borrowings, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Maturities of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Issuances of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Issuances of common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employee payroll taxes related to stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net cash flows provided by (used in) financing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net change in cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Cash, cash equivalents, and restricted cash at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash, cash equivalents, and restricted cash at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Supplemental information: (92) 40 (489) 7 (534) (565) (213) — — 949 308 (17) (7) 455 86 — (956) 8 (862) (494) 337 (24) (350) 798 476 (20) (7) 716 — $ 4 4 $ 1 3 4 $ $ Cash dividends received from consolidated subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 123 $ 105 $ Noncash financing activity – Issuance of common stock for stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 38 (26) — (142) 5 (163) (472) (317) (22) — 450 68 (29) (4) (326) 2 1 3 445 54 AMEREN CORPORATION (parent company only) NOTES TO CONDENSED FINANCIAL STATEMENTS December 31, 2021 NOTE 1 – BASIS OF PRESENTATION Ameren Corporation (parent company only) is a public utility holding company that conducts substantially all of its business operations through its subsidiaries. Ameren Corporation (parent company only) has accounted for its subsidiaries using the equity method. These financial statements are presented on a condensed basis. See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report for additional information. NOTE 2 – CASH AND CASH EQUIVALENTS The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheet and the statement of cash flows as of December 31, 2021 and 2020: (In millions) Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Restricted cash included in “Other current assets” . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total cash, cash equivalents, and restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2021 2020 — $ 4 4 $ — 4 4 See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report for additional information. NOTE 3 – SHORT-TERM DEBT AND LIQUIDITY Ameren, Ameren Services, and other non-state-regulated Ameren subsidiaries have the ability, subject to Ameren parent company and applicable regulatory short-term borrowing authorizations, to access funding from the Credit Agreements and the commercial paper programs through a non-state-regulated subsidiary money pool agreement. All participants may borrow from or lend to the non-state-regulated money pool. The total amount available to pool participants from the non-state-regulated subsidiary money pool at any given time is reduced by the 165 amount of borrowings made by participants, but is increased to the extent that the pool participants advance surplus funds to the non-state- regulated subsidiary money pool or remit funds from other external sources. The non-state-regulated subsidiary money pool was established to coordinate and to provide short-term cash and working capital for the participants. Participants receiving a loan under the non-state- regulated subsidiary money pool agreement must repay the principal amount of such loan, together with accrued interest. The rate of interest depends on the composition of internal and external funds in the non-state-regulated subsidiary money pool. Interest revenues and interest charges related to non-state-regulated money pool advances and borrowings were immaterial in 2019, 2020, and 2021. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for a description and details of short-term debt and liquidity needs of Ameren Corporation (parent company only). NOTE 4 – LONG-TERM OBLIGATIONS See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for additional information on Ameren Corporation’s (parent company only) long-term debt, indenture provisions, forward sale agreements related to common stock, and ATM program. NOTE 5 – COMMITMENTS AND CONTINGENCIES See Note 14 – Commitments and Contingencies under Part II, Item 8, of this report for a description of all material contingencies of Ameren Corporation (parent company only). NOTE 6 – TOTAL OTHER EXPENSE, NET The following table presents the components of “Total Other Expense, Net” in the Condensed Statement of Income and Comprehensive Income for the years ended December 31, 2021, 2020, and 2019: (In millions) Total Other Expense, Net 2021 2020 2019 Non-service cost components of net periodic benefit income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other expense, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Other Expense, Net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1 — (1) — $ $ 1 (8) (1) (8) $ $ 2 (3) (1) (2) 166 SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS FOR THE YEARS ENDED DECEMBER 31, 2021, 2020, AND 2019 (In millions) Ameren: Column A Description Column B Balance at Beginning of Period Column C Column D Column E (1) Charged to Costs and Expenses (2) Charged to Other Accounts(a) Deductions(b) Balance at End of Period Deducted from assets – allowance for doubtful accounts: 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 50 17 18 Ameren Missouri: Deducted from assets – allowance for doubtful accounts: 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 16 $ 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 7 Ameren Illinois: Deducted from assets – allowance for doubtful accounts: 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 34 10 11 9 42 26 5 15 9 4 27 17 $ — $ 6 4 — — — $ $ $ $ 30 15 31 8 6 9 $ — $ 22 $ 6 4 9 22 29 50 17 13 16 7 16 34 10 (a) (b) Amounts associated with the allowance for doubtful accounts relate to the uncollectible account reserve associated with receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. Uncollectible accounts charged off, less recoveries. ITEM 16. FORM 10-K SUMMARY The Ameren Companies elected not to provide a summary of the Form 10-K. 167 EXHIBIT INDEX The documents listed below are being filed or have previously been filed on behalf of the Ameren Companies and are incorporated herein by reference from the documents indicated and made a part hereof. Exhibits not identified as previously filed are filed herewith: Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: Articles of Incorporation/ By-Laws 3.1(i) 3.2(i) 3.3(i) 3.4(i) 3.5(i) 3.6(i) 3.7(ii) 3.8(ii) 3.9(ii) Ameren Ameren Ameren Ameren Restated Articles of Incorporation of Ameren Annex F to Part I of the Registration Statement on Form S-4, File No. 33-64165 Certificate of Amendment to Ameren’s Restated Articles of Incorporation filed December 14, 1998 1998 Form 10-K, Exhibit 3(i), File No. 1-14756 Certificate of Amendment to Ameren’s Restated Articles of Incorporation filed April 21, 2011 April 21, 2011 Form 8-K, Exhibit 3(i), File No. 1-14756 Certificate of Amendment to Ameren’s Restated Articles of Incorporation filed December 18, 2012 December 18, 2012 Form 8-K, Exhibit 3.1(i), File No. 1-14756 Ameren Missouri Restated Articles of Incorporation of Ameren Missouri Ameren Illinois Restated Articles of Incorporation of Ameren Illinois Ameren By-Laws of Ameren, as amended October 8, 2021 1993 Form 10-K, Exhibit 3(i), File No. 1-2967 2010 Form 10-K, Exhibit 3.4(i), File No. 1-3672 October 12, 2021 Form 8-K, Exhibit 3.1, File No. 1-14756 Ameren Missouri Bylaws of Ameren Missouri, as amended February 19, 2021 2020 Form 10-K, Exhibit 3.8(ii), File No. 1-2967 Ameren Illinois Bylaws of Ameren Illinois, as amended February 19, 2021 2020 Form 10-K, Exhibit 3.9(ii), File No. 1-3672 Instruments Defining Rights of Security Holders, Including Indentures 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.9 4.10 4.11 4.12 4.13 Ameren Ameren Ameren Ameren Ameren Ameren Ameren Ameren Ameren Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Indenture, dated as of December 1, 2001 from Ameren to The Bank of New York Mellon Trust Company, N.A., as successor trustee, relating to senior debt securities (Ameren Indenture) Exhibit 4.5, File No. 333-81774 First Supplemental Indenture to Ameren Senior Indenture dated as of May 19, 2008 June 30, 2008 Form 10-Q, Exhibit 4.1, File No. 1-14756 Ameren Indenture Company Order, dated November 24, 2015, establishing the 3.65% Senior Notes due 2026 (including the global note) November 24, 2015 Form 8-K, Exhibits 4.3 and 4.5, File No. 1-14756 Ameren Indenture Company Order, dated September 16, 2019, establishing the 2.50% Senior Notes due 2024 (including the global note) September 16, 2019 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756 Ameren Indenture Company Order, dated April 3, 2020, establishing the 3.50% Senior Notes due 2031 (including the global notes) April 3, 2020 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756 Ameren Indenture Company Order, dated March 5, 2021, establishing the 1.75% Senior Notes due 2028 (including the global note) March 5, 2021 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756 Ameren Indenture Company Order, dated November 18, 2021, establishing the 1.95% Senior Notes due 2027 (including the global note) November 18, 2021 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756 Note Purchase Agreement, dated June 22, 2017, between Ameren Transmission Company of Illinois and the several purchasers named therein. Note Purchase Agreement, dated as of November 16, 2021, between Ameren Transmission Company of Illinois and the several purchasers named therein. Indenture of Mortgage and Deed of Trust, dated June 15, 1937 (Ameren Missouri Mortgage), from Ameren Missouri to The Bank of New York Mellon, as successor trustee, as amended May 1, 1941, and Second Supplemental Indenture dated May 1, 1941 June 26, 2017 Form 8-K, Exhibit 4.1, File No. 1-14756 Exhibit B-1, File No. 2-4940 Supplemental Indenture to the Ameren Missouri Mortgage dated as of July 1, 1956 Exhibit 4.22, File No. 333-222108 Supplemental Indenture to the Ameren Missouri Mortgage dated as of April 1, 1971 Exhibit 4.23, File No. 333-222108 Supplemental Indenture to the Ameren Missouri Mortgage dated as of February 1, 1974 Exhibit 4.24, File No. 333-222108 168 4.14 4.15 4.16 4.17 4.18 4.19 4.20 4.21 4.22 4.23 4.24 4.25 4.26 4.27 4.28 4.29 4.30 4.31 4.32 4.33 4.34 4.35 4.36 4.37 4.38 Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Supplemental Indenture to the Ameren Missouri Mortgage dated as of July 7, 1980 Exhibit 4.25, File No. 333-222108 Supplemental Indenture to the Ameren Missouri Mortgage dated as of October 1, 1993 1993 Form 10-K, Exhibit 4.8, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated as of February 1, 2000 2000 Form 10-K, Exhibit 4.1, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated August 15, 2002 August 23, 2002 Form 8-K, Exhibit 4.3, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated March 5, 2003 relative to Series BB March 11, 2003 Form 8-K, Exhibit 4.4, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004 relative to Series 2004A (1998A) March 31, 2004 Form 10-Q, Exhibit 4.1, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004 relative to Series 2004B (1998B) March 31, 2004 Form 10-Q, Exhibit 4.2, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004 relative to Series 2004C (1998C) March 31, 2004 Form 10-Q, Exhibit 4.3, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004 relative to Series 2004H (1992) March 31, 2004 Form 10-Q, Exhibit 4.8, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated September 1, 2004 relative to Series GG September 23, 2004 Form 8-K, Exhibit 4.4, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated January 1, 2005 relative to Series HH January 27, 2005 Form 8-K, Exhibit 4.4, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated July 1, 2005 relative to Series II July 21, 2005 Form 8-K, Exhibit 4.4, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated June 1, 2008 relative to Series MM June 19, 2008 Form 8-K, Exhibit 4.5, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated March 1, 2009 relative to Series NN March 23, 2009 Form 8-K, Exhibit 4.5, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated May 15, 2012 Exhibit 4.45, File No. 333-182258 Supplemental Indenture to the Ameren Missouri Mortgage dated September 1, 2012 relative to Series OO September 11, 2012 Form 8-K, Exhibit 4.4, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated April 1, 2014 relative to Series PP April 4, 2014 Form 8-K, Exhibit 4.5, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated March 15, 2015 relative to Series QQ April 6, 2015 Form 8-K, Exhibit 4.5, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated June 1, 2017 relative to Series RR June 15, 2017 Form 8-K, Exhibit 4.5, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated April 1, 2018 for 4.000% First Mortgage Bonds due 2048 Supplemental Indenture to the Ameren Missouri Mortgage dated March 1, 2019, for 3.50% First Mortgage Bonds due 2029 Supplemental Indenture to the Ameren Missouri Mortgage dated September 15, 2019, for 3.25% First Mortgage Bonds due 2049 Supplemental Indenture to the Ameren Missouri Mortgage dated March 1, 2020, for 2.95% First Mortgage Bonds due 2030 Supplemental Indenture to the Ameren Missouri Mortgage dated October 1, 2020, for 2.625% First Mortgage Bonds due 2051 Supplemental Indenture to the Ameren Missouri Mortgage dated June 1, 2021, for 2.15% First Mortgage Bonds due 2032 April 6, 2018 Form 8-K, Exhibit 4.2, File No. 1-2967 March 6, 2019 Form 8-K, Exhibit 4.2, File No. 1-2967 October 1, 2019 Form 8-K, Exhibit 4.2, File No. 1-2967 March 20, 2020 Form 8-K, Exhibit 4.2, File No. 1-2967 October 9, 2020 Form 8-K, Exhibit 4.2, File No. 1-2967 June 22, 2021 Form 8-K, Exhibit 4.2, File No. 1-2967 169 4.39 4.40 4.41 4.42 4.43 4.44 4.45 4.46 4.47 4.48 4.49 4.50 4.51 4.52 4.53 4.54 4.55 4.56 4.57 4.58 4.59 4.60 Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Loan Agreement, dated as of December 1, 1992, between the Missouri Environmental Authority and Ameren Missouri, together with Indenture of Trust dated as of December 1, 1992, between the Missouri Environmental Authority and UMB Bank, N.A. as successor trustee to Mercantile Bank of St. Louis, N.A. First Amendment, dated as of February 1, 2004, to Loan Agreement dated as of December 1, 1992, between the Missouri Environmental Authority and Ameren Missouri Series 1998A Loan Agreement, dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri First Amendment, dated as of February 1, 2004, to Series 1998A Loan Agreement dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri Series 1998B Loan Agreement, dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri First Amendment, dated as of February 1, 2004, to Series 1998B Loan Agreement dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri Series 1998C Loan Agreement, dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri First Amendment, dated as of February 1, 2004, to Series 1998C Loan Agreement dated as of September 1, 1998, between the Missouri Environmental Authority and Ameren Missouri Indenture, dated as of August 15, 2002, from Ameren Missouri to The Bank of New York Mellon, as successor trustee (relating to senior secured debt securities) (Ameren Missouri Indenture) First Supplemental Indenture to the Ameren Missouri Indenture, dated as of May 15, 2012 Ameren Missouri Indenture Company Order, dated March 10, 2003, establishing the 5.50% Senior Secured Notes due 2034 (including the global note) Ameren Missouri Indenture Company Order, dated July 21, 2005, establishing the 5.30% Senior Secured Notes due 2037 (including the global note) Ameren Missouri Indenture Company Order, dated March 20, 2009, establishing the 8.45% Senior Secured Notes due 2039 (including the global note) Ameren Missouri Indenture Company Order, dated September 11, 2012, establishing the 3.90% Senior Secured Notes due 2042 (including the global note) Ameren Missouri Indenture Company Order, dated April 4, 2014, establishing the 3.50% Senior Secured Notes due 2024 (including the global note) Ameren Missouri Indenture Company Order, dated April 6, 2015, establishing the 3.65% Senior Secured Notes due 2045 (including the global note) Ameren Missouri Indenture Company Order, dated June 23, 2016, requesting authentication of an additional $150,000,000 aggregate principal amount of 3.65% Senior Secured Notes due 2045 (including the global note) Ameren Missouri Indenture Company Order, dated June 15, 2017, establishing the 2.950% Senior Secured Notes due 2027 (including the global note) Indenture, dated as of December 1, 1998, from Ameren Illinois (formerly Central Illinois Public Service Company) to The Bank of New York Mellon Trust Company, N.A., as successor trustee (CIPS Indenture) 1992 Form 10-K, Exhibit 4.38, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.10, File No. 1-2967 September 30, 1998 Form 10-Q, Exhibit 4.28, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.11, File No. 1-2967 September 30, 1998 Form 10-Q, Exhibit 4.29, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.12, File No. 1-2967 September 30, 1998 Form 10-Q, Exhibit 4.30, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.13, File No. 1-2967 August 23, 2002 Form 8-K, Exhibit 4.1, File No. 1-2967 Exhibit 4.48, File No. 333-182258 March 11, 2003 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 July 21, 2005 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 March 23, 2009 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 September 30, 2012 Form 10-Q, Exhibit 4.1 and September 11, 2012 Form 8-K, Exhibit 4.2, File No. 1-2967 April 4, 2014 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 April 6, 2015 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 June 23, 2016 Form 8-K, Exhibits 4.3, and 4.4, File No. 1-2967 June 15, 2017 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 Exhibit 4.4, File No. 333-59438 First Supplemental Indenture to the CIPS Indenture, dated as of June 14, 2006 June 19, 2006 Form 8-K, Exhibit 4.2, File No. 1-3672 Second Supplemental Indenture to the CIPS Indenture, dated as of March 1, 2010 Exhibit 4.17, File No. 333-166095 Third Supplemental Indenture to the CIPS Indenture, dated as of October 1, 2010 2010 Form 10-K, Exhibit 4.59, File No. 1-3672 170 4.61 4.62 4.63 4.64 4.65 4.66 4.67 4.68 4.69 4.70 4.71 4.72 4.73 4.74 4.75 4.76 4.77 4.78 4.79 4.80 4.81 4.82 4.83 4.84 4.85 Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Illinois Global Note, dated October 1, 2010, representing CIPS Indenture Senior Notes, 6.125% due 2028 Ameren Illinois Global Note, dated October 1, 2010, representing CIPS Indenture Senior Notes, 6.70% Series Secured Notes due 2036 Indenture, dated as of June 1, 2006, from Ameren Illinois (successor in interest to Central Illinois Light Company) to The Bank of New York Mellon Trust Company, N.A., as successor trustee (CILCO Indenture) 2010 Form 10-K, Exhibit 4.60, File No. 1-3672 2010 Form 10-K, Exhibit 4.62, File No. 1-3672 June 19, 2006 Form 8-K, Exhibit 4.3, File No. 1-14756 First Supplemental Indenture to the CILCO Indenture, dated October 1, 2010 October 7, 2010 Form 8-K, Exhibit 4.1, File No. 1-3672 Second Supplemental Indenture to the CILCO Indenture dated as of July 21, 2011 September 30, 2011 Form 10-Q, Exhibit 4.1, File No. 1-3672 Third Supplemental Indenture to the CILCO Indenture, dated as of October 15, 2019 September 30, 2019 Form 10-Q, Exhibit 4.2, File No. 1-3672 CILCO Indenture Company Order, dated June 14, 2006, establishing the 6.70% Senior Secured Notes due 2036 (including the global note) General Mortgage Indenture and Deed of Trust, dated as of November 1, 1992 between Ameren Illinois (successor in interest to Illinois Power Company) and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Ameren Illinois Mortgage) Supplemental Indenture amending the Ameren Illinois Mortgage dated as of December 15, 2002 Supplemental Indenture, dated as of October 1, 2010, to Ameren Illinois Mortgage for Series CIPS-AA and CIPS- CC June 19, 2006 Form 8-K, Exhibit 4.6, File No. 1-14756 1992 Form 10-K, Exhibit 4(cc), File No. 1-3004 December 23, 2002 Form 8-K, Exhibit 4.1, File No. 1-3004 October 7, 2010 Form 8-K, Exhibit 4.9, File No. 1-3672 Supplemental Indenture, dated as of January 15, 2011, to Ameren Illinois Mortgage Exhibit 4.78, File No. 333-182258 Supplemental Indenture, dated as of August 1, 2012, to Ameren Illinois Mortgage for Series EE August 20, 2012 Form 8-K, Exhibit 4.5, File No. 1-3672 Supplemental Indenture, dated as of December 1, 2013, to Ameren Illinois Mortgage for Series FF December 10, 2013 Form 8-K, Exhibit 4.5, File No. 1-3672 Supplemental Indenture, dated as of June 1, 2014, to Ameren Illinois Mortgage for Series GG June 30, 2014 Form 8-K, Exhibit 4.5, File No. 1-3672 Supplemental Indenture, dated as of December 1, 2014, to Ameren Illinois Mortgage for Series HH December 10, 2014 Form 8-K, Exhibit 4.5, File No. 1-3672 Supplemental Indenture, dated as of December 1, 2015, to Ameren Illinois Mortgage for Series II December 14, 2015 Form 8-K, Exhibit 4.5, File No. 1-3672 Supplemental Indenture, dated as of October 25, 2017, to the Ameren Illinois Mortgage September 30, 2017 Form 10-Q, Exhibit 4.1, File No. 1-3672 Supplemental Indenture, dated as of November 1, 2017, to the Ameren Illinois Mortgage for 3.70% First Mortgage Bonds due 2047 Supplemental Indenture, dated as of May 1, 2018, to Ameren Illinois Mortgage for 3.80% First Mortgage Bonds due 2028 Supplemental Indenture, dated as of November 1, 2018, to Ameren Illinois Mortgage for 4.50% First Mortgage Bonds due 2049 November 28, 2017 Form 8-K, Exhibit 4.2, File No. 1-3672 May 22, 2018 Form 8-K, Exhibit 4.2, File No. 1-3672 November 15, 2018 Form 8-K, Exhibit 4.2, File No. 1-3672 Supplemental Indenture, dated as of October 15, 2019, to Ameren Illinois Mortgage for First Mortgage Bonds, Senior Notes Series CILCO-AA September 30, 2019 Form 10-Q, Exhibit 4.3, File No. 1-3672 Supplemental Indenture, dated as of November 1, 2019, to the Ameren Illinois Mortgage for 3.25% First Mortgage Bonds due 2050 Supplemental Indenture, dated as of December 15, 2019, to the Ameren Illinois Mortgage Supplemental Indenture, dated as of November 1, 2020, to Ameren Illinois Mortgage for 1.55% First Mortgage Bonds due 2030 Supplemental Indenture, dated as of June 1, 2021, to Ameren Illinois Mortgage for 0.375% First Mortgage Bonds due 2023 and 2.90% First Mortgage Bonds due 2051 November 26, 2019 Form 8-K, Exhibit 4.2, File No. 1-3672 2019 Form 10-K, Exhibit 4.79, File No. 1-3672 November 23, 2020 Form 8-K, Exhibit 4.2, File No. 1-3672 June 29, 2021 Form 8-K, Exhibit 4.2, File No. 1-3672 171 4.86 4.87 4.88 4.89 4.90 4.91 4.92 4.93 4.94 4.95 4.96 4.97 4.98 4.99 4.100 Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Missouri Ameren Illinois Indenture, dated as of June 1, 2006, from Ameren Illinois (successor in interest to Illinois Power Company) to The Bank of New York Mellon Trust Company, N.A., as successor trustee (Ameren Illinois Indenture) First Supplemental Indenture, dated as of October 1, 2010, to the Ameren Illinois Indenture for Series CIPS-AA and CIPS-CC June 19, 2006 Form 8-K, Exhibit 4.4, File No. 1-14756 October 7, 2010 Form 8-K, Exhibit 4.5, File No. 1-14756 Second Supplemental Indenture to the Ameren Illinois Indenture dated as of July 21, 2011 September 30, 2011 Form 10-Q, Exhibit 4.2, File No. 1-3672 Third Supplemental Indenture to the Ameren Illinois Indenture dated as of May 15, 2012 Exhibit 4.83, File No. 333-182258 Fourth Supplemental Indenture to the Ameren Illinois Indenture, dated as of October 15, 2019 Ameren Illinois Indenture Company Order dated August 20, 2012, establishing the 2.70% Senior Secured Notes due 2022 (including the global note) Ameren Illinois Indenture Company Order dated December 10, 2013, establishing the 4.80% Senior Secured Notes due 2043 (including the global note) Ameren Illinois Indenture Company Order dated June 30, 2014, establishing the 4.30% Senior Secured Notes due 2044 (including the global note) Ameren Illinois Indenture Company Order dated December 10, 2014, establishing the 3.25% Senior Secured Notes due 2025 (including the global note) Ameren Illinois Indenture Company Order dated December 14, 2015, establishing the 4.15% Senior Secured Notes due 2046 (including the global note) Ameren Illinois Indenture Company Order dated December 6, 2016, requesting the authentication of an additional $240,000,000 aggregate principal amount of 4.15% Senior Secured Notes due 2046 (including the global note) September 30, 2019 Form 10-Q, Exhibit 4.4, File No. 1-3672 August 20, 2012 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 December 10, 2013 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 June 30, 2014 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 December 10, 2014 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 December 14, 2015 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 December 6, 2016 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3672 Ameren Illinois Indenture Company Order dated October 30, 2019, establishing Senior Notes Series CILCO-AA (including the global note) September 30, 2019 Form 10-Q, Exhibits 4.5 and 4.6, File No. 1-3672 Description of Ameren Securities Description of Ameren Missouri Securities Description of Ameren Illinois Securities Material Contracts 10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 Ameren Companies Fourth Amended Ameren Corporation System Utility Money Pool Agreement, as amended January 30, 2014 June 30, 2015 Form 10-Q, Exhibit 10.1, File No. 1-14756 Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Ameren Amended and Restated Credit Agreement, dated as of December 9, 2019, by and among Ameren, Ameren Missouri and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto. First Amendment, dated as of November 5, 2021, by and among Ameren, Ameren Missouri and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto to the Amended and Restated Credit Agreement, dated as of December 9, 2019 Amended and Restated Credit Agreement, dated as of December 9, 2019, by and among Ameren, Ameren Illinois and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto. First Amendment, dated as of November 5, 2021, by and among Ameren, Ameren Illinois and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto to the Amended and Restated Credit Agreement, dated as of December 9, 2019 *Summary Sheet of Ameren Corporation Non- Management Director Compensation effective as of January 1, 2022 *Ameren’s Deferred Compensation Plan for Members of the Board of Directors amended and restated effective January 1, 2009, dated June 13, 2008 *Amendment dated October 12, 2009, to Ameren’s Deferred Compensation Plan for Members of the Board of Directors, effective January 1, 2010 172 December 11, 2019 Form 8-K, Exhibit 10.1, File No. 1-2967 December 11, 2019 Form 8-K, Exhibit 10.2, File No. 1-3672 June 30, 2008 Form 10-Q, Exhibit 10.3, File No. 1-14756 2009 Form 10-K, Exhibit 10.15, File No. 1-14756 10.9 10.10 10.11 10.12 10.13 10.14 10.15 10.16 10.17 10.18 10.19 10.20 10.21 10.22 10.23 10.24 10.25 Ameren Companies Ameren Companies Ameren Companies Ameren Companies 10.26 Ameren Companies 10.27 Ameren Companies 10.28 Ameren Companies 10.29 Ameren Companies 10.30 10.31 Ameren Companies Ameren Companies 10.32 Ameren Companies 10.33 Ameren Companies 10.34 Ameren Companies 10.35 Ameren Companies 10.36 Ameren Companies 10.37 10.38 Ameren Companies Ameren Companies Ameren Ameren Ameren Ameren Companies Ameren Companies Ameren Companies Ameren Companies Ameren Companies Ameren Companies Ameren Companies Ameren Companies *Amendment dated October 14, 2010, to Ameren’s Deferred Compensation Plan for Members of the Board of Directors 2010 Form 10-K, Exhibit 10.15, File No. 1-14756 *Ameren’s Deferred Compensation Plan as amended and restated effective January 1, 2010 October 14, 2009 Form 8-K, Exhibit 10.1, File No. 1-14756 *Amendment dated October 14, 2010 to Ameren’s Deferred Compensation Plan 2010 Form 10-K, Exhibit 10.17, File No. 1-14756 *2018 Ameren Executive Incentive Plan 2017 Form 10-K, Exhibit 10.13, File No. 1-14756 *2019 Ameren Executive Incentive Plan 2018 Form 10-K, Exhibit 10.14, File No. 1-14756 *2020 Ameren Short-Term Incentive Plan 2019 Form 10-K, Exhibit 10.17, File No. 1-14756 *2021 Ameren Short-Term Incentive Plan 2020 Form 10-K, Exhibit 10.16, File No. 1-14756 *2022 Ameren Short-Term Incentive Plan *2019 Base Salary Table for Named Executive Officers 2018 Form 10-K, Exhibit 10.19, File No. 1-14756 *2020 Base Salary Table for Named Executive Officers 2019 Form 10-K, Exhibit 10.23, File No. 1-14756 *2021 Base Salary Table for Named Executive Officers 2020 Form 10-K, Exhibit 10.23, File No. 1-14756 Ameren Companies *2022 Base Salary Table for Named Executive Officers Ameren Companies *Second Amended and Restated Ameren Corporation Change of Control Severance Plan 2008 Form 10-K, Exhibit 10.37, File No. 1-14756 October 14, 2009 Form 8-K, Exhibit 10.2, File No. 1-14756 2015 Form 10-K, Exhibit 10.24, File No. 1-14756 2016 Form 10-K, Exhibit 10.24, File No. 1-14756 2017 Form 10-K, Exhibit 10.24, File No. 1-14756 2018 Form 10-K, Exhibit 10.27, File No. 1-14756 2019 Form 10-K, Exhibit 10.32, File No. 1-14756 2020 Form 10-K, Exhibit 10.33, File No. 1-14756 Exhibit 99, File No. 333-196515 2015 Form 10-K, Exhibit 10.31, File No. 1-14756 2016 Form 10-K, Exhibit 10.31, File No. 1-14756 December 13, 2017 Form 8-K, Exhibit 10.1, File No. 1-14756 December 13, 2017 Form 8-K, Exhibit 10.2, File No. 1-14756 2018 Form 10-K, Exhibit 10.34, File No. 1-14756 2018 Form 10-K, Exhibit 10.35, File No. 1-14756 2019 Form 10-K, Exhibit 10.41, File No. 1-14756 *First Amendment dated October 12, 2009, to the Second Amended and Restated Ameren Change of Control Severance Plan *Revised Schedule I to Second Amended and Restated Ameren Change of Control Severance Plan, as amended *Formula for Determining 2016 Target Performance Share Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2017 Target Performance Share Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2018 Target Performance Share Unit and Restricted Stock Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2019 Target Performance Share Unit and Restricted Stock Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2020 Target Performance Share Unit and Restricted Stock Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2021 Target Performance Share Unit and Restricted Stock Unit Awards to be Issued to Named Executive Officers “Formula for Determining 2022 Target Performance Share Unit and Restricted Stock Unit Awards to be Issued to Named Executive Officers *Ameren Corporation 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2016 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2017 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2018 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Restricted Stock Unit Award Agreement for Awards Issued in 2018 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2019 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Restricted Stock Unit Award Agreement for Awards Issued in 2019 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2020 pursuant to 2014 Omnibus Incentive Compensation Plan 173 10.39 Ameren Companies 10.40 Ameren Companies 10.41 Ameren Companies 10.42 Ameren Companies 10.43 10.44 10.45 10.46 10.47 Ameren Companies Ameren Companies Ameren Companies Ameren Companies Ameren Companies *Form of Restricted Share Unit Award Agreement for Awards Issued in 2020 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2021 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Restricted Share Unit Award Agreement for Awards Issued in 2021 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2022 pursuant to 2014 Omnibus Incentive Compensation Plan *Form of Restricted Share Unit Award Agreement for Awards Issued in 2022 pursuant to 2014 Omnibus Incentive Compensation Plan 2019 Form 10-K, Exhibit 10.42, File No. 1-14756 2020 Form 10-K, Exhibit 10.44, File No. 1-14756 2020 Form 10-K, Exhibit 10.45, File No. 1-14756 *Ameren Corporation Severance Plan for Ameren Officers, effective January 1, 2019 2018 Form 10-K, Exhibit 10.36, File No. 1-14756 *Ameren Supplemental Retirement Plan amended and restated effective January 1, 2008, dated June 13, 2008 June 30, 2008 Form 10-Q, Exhibit 10.1, File No. 1-14756 *First Amendment to amended and restated Ameren Supplemental Retirement Plan, dated October 24, 2008 2008 Form 10-K, Exhibit 10.44, File No. 1-14756 *Ameren Corporation 2006 Omnibus Incentive Compensation Plan February 16, 2006 Form 8-K, Exhibit 10.3, File No. 1-14756 Subsidiaries of the Registrant 21.1 Ameren Companies Subsidiaries of Ameren Consent of Experts and Counsel 23.1 23.2 23.3 Power of Attorney 24.1 24.2 24.3 Ameren Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Rule 13a-14(a)/15d-14(a) Certifications 31.1 31.2 31.3 31.4 31.5 31.6 Ameren Ameren Ameren Missouri Ameren Missouri Ameren Illinois Ameren Illinois Section 1350 Certifications 32.1 32.2 32.3 Ameren Ameren Missouri Ameren Illinois Additional Exhibits 99.1 Ameren Companies Interactive Data Files 101.INS 101.SCH Ameren Companies Ameren Companies Consent of Independent Registered Public Accounting Firm with respect to Ameren Consent of Independent Registered Public Accounting Firm with respect to Ameren Missouri Consent of Independent Registered Public Accounting Firm with respect to Ameren Illinois Powers of Attorney with respect to Ameren Powers of Attorney with respect to Ameren Missouri Powers of Attorney with respect to Ameren Illinois Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Missouri Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Missouri Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren Illinois Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Illinois Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Missouri Section 1350 Certification of Principal Executive Officer and Principal Financial Officer of Ameren Illinois Amended and Restated Tax Allocation Agreement, dated as of November 21, 2013 2013 Form 10-K, Exhibit 99.1, File No. 1-14756 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 XBRL Taxonomy Extension Schema Document 174 101.CAL 101.LAB 101.PRE 101.DEF Ameren Companies Ameren Companies Ameren Companies Ameren Companies 104 Ameren Companies XBRL Taxonomy Extension Calculation Linkbase Document XBRL Taxonomy Extension Label Linkbase Document XBRL Taxonomy Extension Presentation Linkbase Document XBRL Taxonomy Extension Definition Document Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) The file number references for the Ameren Companies’ filings with the SEC are: Ameren, 1-14756; Ameren Missouri, 1-2967; and Ameren Illinois, 1-3672. *Compensatory plan or arrangement. 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. 175 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. The signatures for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries. SIGNATURES Date: February 22, 2022 AMEREN CORPORATION (registrant) By /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. President and Chief Executive Officer Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated. /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. /s/ Michael L. Moehn Michael L. Moehn /s/ Theresa A. Shaw Theresa A. Shaw * Warner L. Baxter * Cynthia J. Brinkley * Catherine S. Brune * J. Edward Coleman * Ward H. Dickson Noelle K. Eder * * Ellen M. Fitzsimmons Rafael Flores * * Richard J. Harshman Craig S. Ivey * * James C. Johnson * Steven H. Lipstein * Leo S. Mackay, Jr. *By /s/ Michael L. Moehn Michael L. Moehn Attorney-in-Fact President and Chief Executive Officer, and Director (Principal Executive Officer) February 22, 2022 Executive Vice President and Chief Financial Officer (Principal Financial Officer) Senior Vice President, Finance, and Chief Accounting Officer (Principal Accounting Officer) Director Director Director Director Director Director Director Director Director Director Director Director Director 176 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 Date: February 22, 2022 UNION ELECTRIC COMPANY (registrant) By /s/ Mark C. Birk Mark C. Birk Chairman and President Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated. /s/ Mark C. Birk Mark C. Birk /s/ Michael L. Moehn Michael L. Moehn /s/ Theresa A. Shaw Theresa A. Shaw * Bhavani Amirthalingam Fadi M. Diya * * Chonda J. Nwamu *By /s/ Michael L. Moehn Michael L. Moehn Attorney-in-Fact Chairman and President, and Director (Principal Executive Officer) February 22, 2022 Executive Vice President and Chief Financial Officer, and Director (Principal Financial Officer) February 22, 2022 Senior Vice President, Finance, and Chief Accounting Officer (Principal Accounting Officer) February 22, 2022 Director Director Director February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 177 Date: February 22, 2022 AMEREN ILLINOIS COMPANY (registrant) By /s/ Richard J. Mark Richard J. Mark Chairman and President Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated. /s/ Richard J. Mark Richard J. Mark /s/ Michael L. Moehn Michael L. Moehn /s/ Theresa A. Shaw Theresa A. Shaw * Chonda J. Nwamu * Patrick E. Smith * David N. Wakeman *By /s/ Michael L. Moehn Michael L. Moehn Attorney-in-Fact Chairman and President, and Director (Principal Executive Officer) February 22, 2022 Executive Vice President and Chief Financial Officer, and Director (Principal Financial Officer) February 22, 2022 Senior Vice President, Finance, and Chief Accounting Officer (Principal Accounting Officer) Director Director Director February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 February 22, 2022 178 RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER OF AMEREN CORPORATION (required by Section 302 of the Sarbanes-Oxley Act of 2002) Exhibit 31.1 I, Martin J. Lyons, Jr., certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Corporation; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. President and Chief Executive Officer (Principal Executive Officer) RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER OF AMEREN CORPORATION (required by Section 302 of the Sarbanes-Oxley Act of 2002) Exhibit 31.2 I, Michael L. Moehn, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Corporation; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER OF UNION ELECTRIC COMPANY (required by Section 302 of the Sarbanes-Oxley Act of 2002) Exhibit 31.3 I, Mark C. Birk, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Union Electric Company; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Mark C. Birk Mark C. Birk Chairman and President (Principal Executive Officer) RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER OF UNION ELECTRIC COMPANY (required by Section 302 of the Sarbanes-Oxley Act of 2002) Exhibit 31.4 I, Michael L. Moehn, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Union Electric Company; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) Exhibit 31.5 RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER OF AMEREN ILLINOIS COMPANY (required by Section 302 of the Sarbanes-Oxley Act of 2002) I, Richard J. Mark, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Illinois Company; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Richard J. Mark Richard J. Mark Chairman and President (Principal Executive Officer) RULE 13a-14(a)/15d-14(a) CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER OF AMEREN ILLINOIS COMPANY (required by Section 302 of the Sarbanes-Oxley Act of 2002) Exhibit 31.6 I, Michael L. Moehn, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Illinois Company; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. Date: February 22, 2022 /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) SECTION 1350 CERTIFICATION OF AMEREN CORPORATION (required by Section 906 of the Sarbanes-Oxley Act of 2002) Exhibit 32.1 In connection with the report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Corporation (the “Registrant”) as filed by the Registrant with the Securities and Exchange Commission on the date hereof (the “Form 10-K”), each undersigned officer of the Registrant does hereby certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: (1) (2) The Form 10-K fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and The information contained in the Form 10-K fairly presents, in all material respects, the financial condition and results of operations of the Registrant. Date: February 22, 2022 /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. President and Chief Executive Officer (Principal Executive Officer) /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) SECTION 1350 CERTIFICATION OF UNION ELECTRIC COMPANY (required by Section 906 of the Sarbanes-Oxley Act of 2002) Exhibit 32.2 In connection with the report on Form 10-K for the fiscal year ended December 31, 2021, of Union Electric Company (the “Registrant”) as filed by the Registrant with the Securities and Exchange Commission on the date hereof (the “Form 10-K”), each undersigned officer of the Registrant does hereby certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: (1) (2) The Form 10-K fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and The information contained in the Form 10-K fairly presents, in all material respects, the financial condition and results of operations of the Registrant. Date: February 22, 2022 /s/ Mark C. Birk Mark C. Birk Chairman and President (Principal Executive Officer) /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) SECTION 1350 CERTIFICATION OF AMEREN ILLINOIS COMPANY (required by Section 906 of the Sarbanes-Oxley Act of 2002) Exhibit 32.3 In connection with the report on Form 10-K for the fiscal year ended December 31, 2021, of Ameren Illinois Company (the “Registrant”) as filed by the Registrant with the Securities and Exchange Commission on the date hereof (the “Form 10-K”), each undersigned officer of the Registrant does hereby certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: (1) (2) The Form 10-K fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and The information contained in the Form 10-K fairly presents, in all material respects, the financial condition and results of operations of the Registrant. Date: February 22, 2022 /s/ Richard J. Mark Richard J. Mark Chairman and President (Principal Executive Officer) /s/ Michael L. Moehn Michael L. Moehn Executive Vice President and Chief Financial Officer (Principal Financial Officer) Investor Information GA AP TO CORE EARNINGS PER SHARE RECONCILIATIONS Year Ended Dec. 31, 2013 2014 2015 2016 2017 2018 2019 2020 2021 GAAP Diluted EPS $1.18 $2.40 $2.59 $2.68 $2.14 $3.32 $3.35 $3.50 $3.84 Exclude results from discontinued operations 0.87 — (0.01) — — — — — — Less: Income tax expense / (benefit) 0.05 — (0.20) — — — — — — Exclude provision for discontinuing pursuit of a license for a second nuclear unit at the Callaway Energy Center — — 0.29 — — — — — — Less: Income tax benefit — — (0.11) — — — — — — Charge for revaluation of deferred taxes resulting from increased Illinois state income tax rate — — — — 0.09 — — — — Less: Federal income tax benefit — — — — (0.03) — — — — Charge for revaluation of deferred taxes resulting from decreased federal income tax rate — — — — 0.66 0.05 — — — Less: State income tax benefit — — — — (0.03) — — — — Core Diluted EPS $2.10 $2.40 $2.56 $2.68 $2.83 $3.37 $3.35 $3.50 $3.84 WEATHER-NORMALIZED EARNINGS PER SHARE RECONCILIATIONS Year Ended Dec. 31, 2013 2014 2015 2016 2017 2018 2019 2020 2021 Core1 Diluted EPS $2.10 $2.40 $2.56 $2.68 $2.83 $3.37 $3.35 $3.50 $3.84 Effects of weather at Ameren Missouri Less: Income tax expense Weather impact, net of tax expense 0.03 (0.01) 0.02 0.05 (0.02) 0.03 (0.04) 0.01 (0.03) 0.16 (0.06) 0.10 (0.07) 0.02 (0.05) 0.43 (0.11) 0.32 0.04 (0.01) 0.03 (0.05) 0.01 (0.04) 0.02 0.00 0.02 Core Diluted EPS Normalized for Weather 2 $2.08 $2.37 $2.59 $2.58 $2.88 $3.05 $3.32 $3.54 $3.82 1. See table above for GAAP to core earnings per share reconciliations. 2. From 2013 to 2021, core diluted EPS normalized for weather increased approximately 84%, reflecting an approximately 8% compound annual growth rate, and GAAP diluted EPS increased approximately 225%, reflecting an approximately 16% compound annual growth rate. From 2020 to 2021, core diluted EPS normalized for weather increased approximately 8%, and GAAP diluted EPS increased approximately 9.7%. STOCK EXCHANGE LISTING Ameren's common stock is listed on the New York Stock Exchange. Ameren's ticker symbol is AEE. ANNUAL MEETING The annual meeting of Ameren Corporation shareholders will convene online at 10 a.m. CDT, Thursday, May 12, 2022. The annual shareholder meetings of Ameren Illinois Company and Union Electric Company will be held at the same time. SHAREHOLDER INFORMATION For shareholder inquiries, including enrollment information and a prospectus for Ameren’s DRPlus Dividend Reinvestment and Stock Purchase Plan, which enables participants to purchase Ameren common stock through optional cash reinvestment of dividends, purchases and contact Ameren’s transfer agent, registrar, dividend paying agent, and DRPlus plan administrator, EQ Shareowner Services, at the information shown on the back cover of this report. General shareholder information and certain forms, including transfer instructions, are available at www.shareowneronline.com. DIRECT DEPOSIT OF DIVIDENDS All registered Ameren common and Ameren Illinois Company and Union Electric Company preferred shareholders may have their cash dividends automatically deposited into their bank accounts. This service gives shareholders immediate access to their dividend on the dividend payment date and eliminates the possibility of lost or stolen dividend checks. CORPORATE GOVERNANCE DOCUMENTS Financial reports, including filings with the Securities and Exchange Commission and Ameren's Annual Report on Form 10-K, are available online at amereninvestors.com. Other information about Ameren, including our code of ethics, corporate governance guidelines, and committee charters, is also available at amereninvestors.com. P.O. Box 66149 St. Louis, MO 63166-6149 ameren.com TRANSFER AGENT, REGISTRAR, DIVIDEND PAYING AGENT AND DRPLUS ADMINISTRATOR EQ Shareowner Services Toll free: 800.255.2237 Email: Go to shareowneronline.com and select Contact Us. U.S. Mail EQ Shareowner Services P.O. Box 64874 St. Paul, Minnesota 55164-0874 Overnight Delivery EQ Shareowner Services 1110 Centre Pointe Curve, Suite 101 Mendota Heights, Minnesota 55120-4100 

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