Ameren Annual Report 2013

Plain-text annual report

44607_CvrA.indd 1-3 2/28/14 12:27 AM 44607_CvrA.indd 4-6 2/25/14 11:42 PM At Ameren, our regulated utilities power the economy and the quality of life for millions of people. We’re focused on providing superior returns to our shareholders, safe and reliable energy to our region and excellent service to our customers—now and long into the future. That’s delivering value. CONTENTS 04 Letter from the CEO 14 Executive Leadership Team 08 Positioned for Growth 16 Ofﬁ cers & Board of Directors 11 Reliable Service Now & for the Future 17 Financial Highlights 12 Value at the Meter & Beyond 18 About Ameren 44607_Eds.indd 3 333 3/3/14 9:32 AM LETTER FROM THE CEO My fellow shareholders: 2013 was a pivotal year for Ameren Corporation. In ﬁ nalizing the divestiture of the company’s merchant generation business, Ameren leadership took decisive action to reduce business risk and position your company for sustainable growth. Ameren has clariﬁ ed its value proposition to investors by outlining a clear path forward. The company’s strategy entails investing in its regulated businesses in a manner consistent with existing regulatory frameworks, working to enhance those frameworks and developing and executing on rate-regulated opportunities for future investment for the beneﬁ t of customers and shareholders. By successfully executing this strategy, Ameren expects to continue meeting customers’ energy needs and expectations; earn fair returns on investments; and grow earnings and dividends. // Ringing in the New Year: Ameren entered 2014 focused on its rate-regulated utilities, following the divestiture of its merchant generation business. To mark the occasion, Ameren CEO Tom Voss rang the Jan. 3 closing bell at the New York Stock Exchange. (Also pictured, from left: Doug Fischer, Senior Director, Investor Relations; Marty Lyons, Executive Vice President and Chief Financial Ofﬁ cer; and Matt Thayer, Investor Relations Manager.) 4 44607_Eds.indd 4 3/3/14 9:32 AM EXECUTING ON OUR STRATEGY Throughout the past year, a primary focus has been to reduce business risk. In December, Ameren completed the divestiture of its merchant generation business, Ameren Energy Resources, to an afﬁ liate of Dynegy Inc. The ﬁ nal milestone was reached in January 2014 with the sale of three merchant gas-ﬁ red energy centers to an afﬁ liate of Rockland Capital, LLC. The divestiture improves the predictability of Ameren’s earnings and cash ﬂ ows. Since Ameren announced its intention to exit merchant generation late in 2012, investors have taken notice of Ameren’s overall business strategy, which has included narrowing the gap between allowed and earned returns in our regulated businesses and developing a pipeline of regulated investment opportunities. Ameren begins 2014 as a renewed company focused on its strategic objectives to strengthen and grow its rate-regulated electric, natural gas and transmission operations. In the next few years, it is all about execution in key areas. I. MANAGING THE BUSINESS WELL First, Ameren will continue operating its businesses well and in a manner consistent with existing regulatory frameworks to provide safe and reliable service for our customers in Missouri and Illinois. Ameren’s plan is to allocate increasing amounts of discretionary capital to businesses operating under constructive regulatory frameworks. Planned investments in regulated transmission, distribution and generation will drive enhanced shareholder value while helping sustain reliable service for customers and increasing access to renewable energy. As a result of disciplined management: (cid:2) Earned returns at our utilities have increased. (cid:2) Delivery service system reliability has improved. (see page 11) (cid:2) Electric rates have remained reasonably priced. (see page 18) I also want to stress that there is nothing more important than the safety of our workforce, and in 2013 Ameren continued to build a culture where unsafe acts are neither committed nor accepted. OUTPERFORMING OUR PEERS % CHANGE 125 115 105 95 12.19.12 3.31.13 6.30.13 9.30.13 12.31.13 AMEREN PHILADELPHIA UTILITY INDEX // Ameren stock (AEE) has outperformed the broader utility index (UTY) since the December 2012 announcement to exit the merchant generation business. The total return for Ameren shareholders also was in the top quartile of peers for 2013. II. ENHANCING REGULATORY FRAMEWORKS Second, Ameren is diligently working to enhance the regulatory frameworks under which the company’s businesses operate. Utilities are among the nation’s most capital-intensive industries, producing and delivering the energy essential for our modern lives. My colleagues and I meet frequently with lawmakers, business leaders, labor organizations and other key stakeholders with a goal of ﬁ nding constructive ways to enable critical utility investment. Illinois has made notable progress. In 2011, lawmakers passed the Energy Infrastructure Modernization Act (EIMA) that provided for formulaic electric ratemaking. In 2013, the legislature amended the EIMA, making constructive clariﬁ cations to the ratemaking formula. Also in 2013, the governor signed the Natural Gas Consumer, Safety & Reliability Act, which provides a framework for gas delivery infrastructure surcharges for qualiﬁ ed investments. These actions bring Illinois into further alignment with dozens of other states that have recognized the need for timely cost recovery mechanisms that encourage much-needed infrastructure investments. 44607_Eds.indd 5 5 3/3/14 9:32 AM ANNUAL MEETING 9 a.m. Thursday, April 24, 2014 Saint Louis Art Museum One Fine Arts Drive, Forest Park St. Louis, Mo. Ameren also has sought and received constructive rate treatment for transmission investments overseen by the Federal Energy Regulatory Commission (FERC). FERC’s formulaic rate treatment applies to Ameren Illinois, which is focused on developing, owning and operating transmission projects that meet local needs, as well as Ameren Transmission Company of Illinois (ATXI), which is focused on projects that address regional needs. In Missouri, challenges remain due to the lack of a modern framework for timely recovery of costs related to capital investments. This framework does not lead to the investments that Missourians want and need to address aging infrastructure. Given this regulatory reality, we are limiting the growth in Missouri investments. Elected ofﬁ cials in Missouri have stated that energy is a priority in 2014, and we’ll continue to work with them to enhance the regulatory framework. III. DEVELOPING INVESTMENT OPPORTUNITIES Third, Ameren has identiﬁ ed signiﬁ cant investment opportunities that will create jobs and generate broader beneﬁ ts for our region, including: (cid:2) Modernized infrastructure that keeps our economy moving forward. (cid:2) Contracting opportunities for small businesses, including diverse-owned suppliers. (cid:2) More information and convenience for our customers. (cid:2) Increased access to renewable energy. Here’s an update on the progress. Ameren Illinois In electric delivery, Ameren Illinois is executing its Modernization Action Plan (MAP). This decade-long plan calls for an estimated $640 million in investments to support reliability and integrate technology into the grid. This includes installing advanced meters for 780,000 customers, an effort that started in 2014. These safe, cyber-secure meters will enable the Illinois team to more quickly pinpoint and restore service disruptions. The Modernization Action Plan also is designed to create jobs and enable energy innovation. Since 2012, 540 jobs have been created by MAP. August 2013 saw the opening of Ameren Illinois’ Technology Applications Center, located near the University of Illinois Urbana-Champaign Research Park. The center features a working electric distribution system that lets entrepreneurs test new products including the latest “smart” appliances. Customers already are seeing smart grid improvements at work. Last spring, for example, lightning caused a major fault to an East Peoria, Ill., substation. A newly installed automated switch initiated a power transfer, restoring service to nearly 1,100 people in minutes rather than hours. This automation represents a transformative change to Illinois’ power grid. I invite you to view an interactive map of ongoing Illinois electric delivery projects at AmerenIllinois.com. In natural gas delivery, Ameren Illinois plans to participate in the framework established by the state’s new gas act. The Arctic air mass that blasted the Midwest early this year reminds us how critical natural gas is for heating homes and businesses. Over the next 10 years, Ameren Illinois plans to invest capital to further strengthen the integrity of its system and install approximately 450,000 advanced gas meters that will enable customers to better manage their energy consumption and reduce costs. 6 44607_Eds.indd 6 3/3/14 9:32 AM FERC-regulated electric transmission Ameren’s most signiﬁ cant opportunities lie in large- scale transmission projects. The company plans to invest approximately $2.25 billion from 2014 to 2018 in FERC-regulated electric transmission. The single-largest investment is the Illinois Rivers project, a 345-kilovolt line stretching from east of Quincy, Ill., to the Indiana border. The Illinois Commerce Commission ﬁ nalized its Certiﬁ cate of Public Convenience and Necessity for the project in February. Substation construction is already underway, and line construction is expected to commence later this year. Ameren Missouri In Missouri, the primary focus will be to continue maintaining infrastructure, which includes replacing the reactor head at Callaway Energy Center and constructing additional environmental controls at Labadie Energy Center. Ameren Missouri also recently announced plans to build what will be the state’s largest investor-owned solar facility. Construction of this utility-scale energy center, featuring more than 19,000 solar panels, begins this spring. Ameren wants to power the quality of life for customers with a diverse mix of energy sources, including renewables. I encourage all shareholders to view the 2013 Corporate Social Responsibility Report, which discusses Ameren’s approach to community betterment, environmental stewardship and ﬁ nancial strength. It is available at Ameren.com/CSR. RELENTLESS IMPROVEMENT Since 2009, when I took over as CEO, we’ve improved Ameren’s credit ratings; raised the dividend; and outlined a clear path to grow earnings and dividends. Through the end of 2013, Ameren’s stock price has increased 57%, representing more than $2.8 billion in shareholder value, and during that time Ameren also has paid out more than $1.7 billion in dividends. Looking ahead, expect our signiﬁ cant investment plans to translate into strong earnings growth and a strong dividend. This is critical because healthy ﬁ nancial performance is essential to Ameren’s mission to power the quality of life for an estimated combined population of 6.3 million people in some 1,700 Illinois and Missouri communities. On a personal note, this will be my last letter to you after serving the past ﬁ ve years as CEO. When I retire from Ameren on July 1 after more than four decades, I’ll be leaving behind an exceptional leadership team to execute our strategic plan. Ameren will be in capable hands with Warner Baxter, who in February was named President and will succeed me as CEO. The Board of Directors and I are conﬁ dent Warner has the talent and tenacity to lead our team in the successful execution of the corporate strategy that has positioned Ameren for growth. And ﬁ nally, I want to thank all our employees for being relentless in focusing on operational excellence so we can deliver value for customers and shareholders. Thank you for your trust and loyalty. Thomas R. Voss Chairman & Chief Executive Ofﬁ cer Ameren Corporation February 2014 44607_Eds.indd 7 77 3/3/14 9:32 AM POSITIONED FOR GROWTH PLANNED CAPITAL INVESTMENT ALLOCATION Ameren’s business strategy is designed to deliver top-tier shareholder returns while providing the reliable and safe energy that our customers expect. From 2014-2018, Ameren plans to invest approximately $8.3 billion in our regulated utilities. We believe these investments will create value for all of our stakeholders, including jobs and economic development for the communities we serve. Transmission $2.25 Billion Investing in projects that improve grid efﬁ ciency and support customer load growth. Our single-largest undertaking is the nearly 400-mile Illinois Rivers project, which will help integrate renewable energy into the grid. Illinois Regulated Delivery $2.65 Billion Modernizing the electric grid— including installing “smart” technology that can detect and isolate outages—and investing in gas transmission, storage and distribution infrastructure to support safe, reliable service. Missouri Environmental $300 Million Proactively investing to stay ahead of evolving regulations and to be good stewards of our environment. A major project will involve installing new electrostatic precipitators at the Labadie Energy Center to remove ﬁ ne particulates and enhance air quality. Missouri Regulated $3.05 Billion Maintaining reliability for our customers by performing inspections and replacing critical infrastructure. Signiﬁ cant projects include replacing the nuclear reactor vessel head at Callaway Energy Center. 6% EXPECTED COMPOUND ANNUAL GROWTH IN RATE BASE Ameren’s infrastructure investment plans translate into expected overall rate base growth of about 6% compounded annually through 2018. This growth rate is expected to be above the peer group average. 8 44607_Eds.indd 8 3/3/14 9:32 AM “ Ameren’s investment plan, coupled with disciplined cost control, is expected to lead to solid earnings per share growth in 2014. We expect earnings per share to grow at a 7% to 10% compound annual rate from 2013 to 2018—a rate better than the expected average of our regulated peers. ” MARTIN J. LYONS, JR., EXECUTIVE VICE PRESIDENT AND CHIEF FINANCIAL OFFICER 44607_Eds.indd 9 9 3/3/14 9:32 AM 10 44607_Eds.indd 10 3/3/14 9:32 AM RELIABLE SERVICE NOW & FOR THE FUTURE Reliable energy is essential to the health of our region’s economy and to our customers’ way of life—at home, at work and at play. That’s why Ameren is focused on ensuring reliable electricity and natural gas service. We continually upgrade our vast energy transmission and delivery systems. In 2013, for example, Ameren Missouri started the St. Louis Downtown Revitalization Project to renew the electric grid in an area where some facilities, conduits and manholes are a century old. Customers can track ongoing construction at AmerenMissouri.com. More and more, we’re tapping into technology to boost the performance of our interconnected infrastructure. In the coming years, Ameren’s systems in Missouri and Illinois will continue to beneﬁ t from the latest reliability technology, which includes remote monitoring to detect gas leaks and intelligent switches that can isolate power outages. These types of upgrades enable Ameren to meet our customers’ needs and expectations in the years to come. “We’re focused on improving service reliability for our customers. Implementing new technology and software is a central component of our plan to upgrade the grid.” Ron Pate, Senior Vice President, Operations and Technical Services, Ameren Illinois // Forward Progress: Candidates for electric lineman apprentice positions participate in exercises at the new Metro East Training Center in Belleville, Ill., where workers are learning about the latest “smart” technologies for electric and gas delivery service. The facility opened in October 2013 as part of Ameren Illinois’ Modernization Action Plan to create jobs and enable energy innovation. IMPROVING RELIABILITY = BETTER 1.25 1.00 0.50 0.25 2008 2009 2010 2011 2012 2013 // Ameren’s electric distribution reliability performance has steadily improved and in 2013 was the best ever measured across the corporation. System Average Interruption Frequency Index (SAIFI), which shows average number of outages per customer, per year. In 2013, corporation-wide SAIFI was 0.89. 44607_Eds.indd 11 11 3/3/14 9:32 AM VALUE AT THE METER & BEYOND The value Ameren brings to our customers doesn’t start and stop at the meter. Every touchpoint counts. So we’re taking action to ensure that customers are informed about their accounts and feel empowered to manage their energy usage. And when they have questions, they can turn to us for answers. In 2013, Ameren focused on further improving the digital experience for our customers, including easier enrollment for eBill, Direct Pay and Budget Billing. Customers also can receive timely updates on bill reminders, payment notices, the status of reported outages and more via text or email. 5:50 PM Ameren: PAYMENT RECEIVED Acct ending 1234 a... To sign up, customers can text REG to 40401 or visit Ameren.com/alerts. Message and data rates apply. “As more of our customers use smartphones and tablets, it’s essential that we provide value by offering tools that meet their expectations.” Robin Hadley, General Supervisor, Performance Management, Ameren Illinois 3/3/14 9:33 AM // Committed to Our Communities: Adriann Adams-Gulley, President of Delta Sigma Theta, and Richard Mark, President and CEO, Ameren Illinois, show Chloe Henry one of the toys handed out during the sorority’s 2013 Breakfast with Santa in East St. Louis. By supporting worthwhile causes, our company and co-workers build stronger communities. // Helping Customers Stay Safe: Warner Baxter, President, Ameren Corporation, loads one of 240 ENERGY STAR® air conditioners donated to Cool Down St. Louis last summer. Numerous agencies distributed the units to elderly residents and people with disabilities. 12 44607_Eds.indd 12 // Bright Ways to Save: Thanks to a meaningful change to Missouri’s regulatory framework, Ameren Missouri in 2013 launched the largest customer energy-savings program in state history. Notre Dame Regional High School in Cape Girardeau, Mo., received more than $5,000 from Ameren Missouri’s ActOnEnergy BizSavers® program to install energy-efﬁ cient lighting in its gymnasium. “It’s an investment that saves energy and money year after year, while providing a better environment for the people who use these energy- efﬁ cient buildings,” said Brad Wittenborn, Assistant Principal. The school expects to save more than 96,000 kWh of electricity annually. Meanwhile, Ameren Illinois customers realized nearly $140 million in savings on their electric and gas bills in 2013 by taking advantage of rebates and incentives available through ActOnEnergy programs, which have been in place since 2008. Learn more at ActOnEnergy.com. 13 44607_Eds.indd 13 3/3/14 9:33 AM AMEREN EXECUTIVE LEADERSHIP TEAM Listing current as of Feb. 28, 2014. * Ofﬁ cer of an Ameren Corporation subsidiary only. Maureen A. Borkowski* Chairman, President and Chief Executive Ofﬁ cer, Ameren Transmission Company of Illinois Michael L. Moehn* Senior Vice President, Customer Operations, Ameren Missouri Martin J. Lyons, Jr. Executive Vice President and Chief Financial Ofﬁ cer, Ameren Corporation Mark C. Lindgren* Vice President and Chief Human Resources Ofﬁ cer, Ameren Services Richard J. Mark* Chairman, President and Chief Executive Ofﬁ cer, Ameren Illinois 14 44607_Eds.indd 14 3/3/14 9:33 AM Thomas R. Voss Chairman and Chief Executive Ofﬁ cer, Ameren Corporation Warner L. Baxter President, Ameren Corporation Gregory L. Nelson Senior Vice President, General Counsel and Secretary, Ameren Corporation Mary P. Heger* Vice President, Information Technology, Ameren Services Center, and Chief Information Ofﬁ cer, Ameren Services Daniel F. Cole* Chairman, President and Chief Executive Ofﬁ cer, Ameren Services Charles D. Naslund* Executive Vice President, Ameren Missouri 44607_Eds.indd 15 15 3/3/14 9:34 AM AMEREN CORPORATION AND SUBSIDIARIES OFFICERS Lynn M. Barnes* Vice President, Business Planning and Controller, Ameren Missouri Scott A. Glaeser* Vice President, Gas Operations and Technical Services, Ameren Illinois Ryan J. Martin Assistant Vice President and Treasurer, Ameren Corporation Ronald D. Pate* Senior Vice President, Operations and Technical Services, Ameren Illinois Mark C. Birk* Senior Vice President, Corporate Planning and Business Risk Management, Ameren Services S. Mark Brawley Vice President, Internal Audit, Ameren Corporation Kendall D. Coyne* Vice President, Tax, Ameren Services Kevin A. DeGraw* Vice President, Power Operations, Ameren Missouri Fadi M. Diya* Senior Vice President and Chief Nuclear Ofﬁ cer, Ameren Missouri Sharon Harvey Davis* Vice President and Chief Diversity Ofﬁ cer, Ameren Services Michael L. Menne* Vice President, Environmental Services, Ameren Services David R. Hunt* Vice President, Corporate Communications and Brand Management, Ameren Services Michael G. Mueller* Vice President, Energy Trading and Fuels Commodities, Ameren Missouri Craig D. Nelson* Senior Vice President, Regulatory Affairs and Financial Services, Ameren Illinois David W. Neterer* Vice President, Engineering, Callaway Nuclear Plant, Ameren Missouri Christopher A. Iselin* Senior Vice President, Corporate Operations Oversight, Ameren Services Stephen M. Kidwell* Vice President, Corporate Planning, Ameren Services Geralynn M. Lord* Assistant Vice President, Corporate Communications and Brand Management, Ameren Services Joseph M. Power* Vice President, Federal Legislative and Regulatory Affairs, Ameren Services Cleveland O. Reasoner* Vice President, Nuclear Operations, Callaway Nuclear Plant, Ameren Missouri Shawn E. Schukar* Senior Vice President, Business Development, Ameren Transmission Company of Illinois Theresa A. Shaw Assistant Vice President and Controller, Ameren Corporation Stan E. Ogden* Vice President, Customer Service and Metering Operations, Ameren Illinois James A. Sobule* Vice President and Deputy General Counsel, Ameren Services Bruce A. Steinke Senior Vice President, Finance and Chief Accounting Ofﬁ cer, Ameren Corporation David N. Wakeman* Vice President, Energy Delivery- Distribution Services, Ameren Missouri Dennis W. Weisenborn* Vice President, Safety and Supply Services, Ameren Services D. Scott Wiseman* Vice President, External Affairs, Ameren Illinois Warren T. Wood* Vice President, Regulatory and Legislative Affairs, Ameren Missouri The ofﬁ cers also include the Ameren Executive Leadership Team on pages 14-15. The ofﬁ cer listing is as of Feb. 28, 2014. * Ofﬁ cer of an Ameren Corporation subsidiary only. BOARD OF DIRECTORS Warner L. Baxter President, Ameren Corporation Catherine S. Brune Retired President, East Territory, Allstate Insurance Company Audit and Risk Committee; Nuclear Oversight and Environmental Committee Ellen M. Fitzsimmons Executive Vice President of Law and Public Affairs, General Counsel and Corporate Secretary, CSX Corporation Audit and Risk Committee; Nominating and Corporate Governance Committee Walter J. Galvin Retired Vice Chairman, Emerson Electric Co. Finance Committee; Audit and Risk Committee; Lead Director Richard J. Harshman Chairman, President and Chief Executive Ofﬁ cer, Allegheny Technologies Incorporated Nominating and Corporate Governance Committee; Nuclear Oversight and Environmental Committee Dr. Gayle P. W. Jackson President and Chief Executive Ofﬁ cer, Energy Global, Inc. Nominating and Corporate Governance Committee; Nuclear Oversight and Environmental Committee James C. Johnson Retired General Counsel, Loop Capital Markets, LLC Human Resources Committee; Nominating and Corporate Governance Committee Steven H. Lipstein President and Chief Executive Ofﬁ cer, BJC HealthCare Finance Committee; Human Resources Committee Patrick T. Stokes Former Chairman, Anheuser-Busch Companies, Inc. Finance Committee; Human Resources Committee Thomas R. Voss Chairman and Chief Executive Ofﬁ cer, Ameren Corporation Stephen R. Wilson Retired Chairman, President and Chief Executive Ofﬁ cer, CF Industries Holdings, Inc. Finance Committee; Audit and Risk Committee Jack D. Woodard Retired Executive Vice President and Chief Nuclear Ofﬁ cer, Southern Nuclear Operating Company, Inc. Human Resources Committee; Nuclear Oversight and Environmental Committee 16 44607_Eds.indd 16 3/3/14 9:34 AM FINANCIAL HIGHLIGHTS Ameren Consolidated In millions, except per share amounts and as noted Results of Operations Operating revenues Operating expenses Operating income Net income attributable to Ameren Corporation from continuing operations Net income (loss) attributable to Ameren Corporation from discontinued operations Net income (loss) attributable to Ameren Corporation Common Stock Data Continuing operations earnings per diluted share Discontinued operations earnings (loss) per diluted share Earnings (loss) per diluted share Dividends per common share Dividend yield (year-end) Market price per common share (year-end closing) Shares outstanding (weighted average) Total market value of common shares (year-end) Book value per common share Balance Sheet Data Property and plant, net Total assets Long-term debt obligations, excluding current maturities Capitalization Ratios Common equity Preferred stock, not subject to mandatory redemption Debt and preferred stock subject to mandatory redemption, net of cash Operating Data (continuing operations) Total electric sales (kilowatt-hours) Native natural gas sales (decatherms in thousands) Total generation output (kilowatt-hours) Electric customers Natural gas customers 2013 2012 2011 Years ended December 31 $ $ $ $ $ $ $ $ $ $ 5,838 4,654 1,184 512 (223) 289 2.10 (0.92) 1.18 1.600 4.4% $ $ $ $ 5,781 4,593 1,188 516 $ (1,490) $ (974) $ $ $ $ 2.13 (6.14) (4.01) 1.600 5.2% $ $ $ $ $ $ $ $ $ $ 6,148 5,115 1,033 431 88 519 1.79 0.36 2.15 1.555 4.7% $ 36.16 $ 30.72 $ 33.13 $ $ $ $ $ 242.6 8,772 26.97 16,205 21,042 5,504 50.1% 1.1% 48.8% 80,057 195,266 43,213 2.4 0.9 $ $ $ $ $ 242.6 7,453 27.27 15,348 22,230 5,802 52.0% 1.1% 46.9% 81,680 172,647 44,658 2.4 0.9 $ $ $ $ $ 241.5 8,037 32.64 14,848 23,723 5,853 56.6% 1.0% 42.4% 85,588 178,313 48,741 2.4 0.9 44607_Eds.indd 17 17 3/3/14 9:34 AM ABOUT AMEREN Ameren Corporation is a Fortune 500 company. We pride ourselves on a tradition of ﬁ nancial strength, cost containment, reasonably priced energy and highly rated customer service, as well as more than 100 years of uninterrupted cash dividend payments to shareholders. Our workforce of about 8,500 serves approximately 2.4 million electric and more than 900,000 natural gas customers across 64,000 square miles. ELECTRICITY PRICES SERVICE TERRITORY Ameren Blended 9.87 ¢/kWh Chicago 11.76 ¢/kWh San Francisco 16.98 ¢/kWh Detroit 15.36 ¢/kWh Cleveland 11.55 ¢/kWh New York 26.73 ¢/kWh Philadelphia 14.96 ¢/kWh Los Angeles 13.58 ¢/kWh Atlanta 11.95 ¢/kWh San Antonio 9.77 ¢/kWh Miami 10.41 ¢/kWh Ameren’s residential electricity prices are below the national average of 12.09 ¢/kWh. By focusing on operational excellence and disciplined capital management, we can offer reasonably priced energy to millions of people in our service territory. Chart based on revenues and sales report available through the Energy Information Administration (www.eia.gov) for the 12 months ending October 2013. Shows weighted average of Ameren utilities residential electric prices. Ameren Illinois electricity price has been adjusted to reﬂ ect the price of basic generation service to the residential class. St. Louis Collinsville Ameren Missouri This utility owns a mix of electricity generation facilities, with 10,300 MW capacity. It is the largest electric utility and the second-largest gas distributor in the state. Ameren Illinois This delivery-only utility is the second-largest electric distributor and the third-largest gas distributor in the state. Corporate Headquarters Subsidiary Headquarters Electric Service Territory Electric & Natural Gas Service Territory 18 44607_Eds.indd 18 3/3/14 9:34 AM UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-K (X) Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the fiscal year ended December 31, 2013. 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) 6 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: Registrant Ameren Corporation Securities Registered Pursuant to Section 12(g) of the Act: Registrant Union Electric Company Ameren Illinois Company Title of each class Common Stock, $0.01 par value per share Title of each class Preferred Stock, cumulative, no par value, stated value $100 per share Preferred Stock, cumulative, $100 par value per share Depositary Shares, each representing one-fourth of a share of 6.625% Preferred Stock, cumulative, $100 par value per share 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 (X) ( ) ( ) No No No ( ) (X) (X) 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 (X) (X) (X) 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 (X) (X) (X) No No No ( ) ( ) ( ) Indicate by checkmark whether each registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Ameren Corporation Union Electric Company Ameren Illinois Company Yes Yes Yes (X) (X) (X) No No No ( ) ( ) ( ) Indicate by checkmark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of each registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. Ameren Corporation Union Electric Company Ameren Illinois Company (X) (X) (X) Indicate by checkmark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. Ameren Corporation Union Electric Company Ameren Illinois Company Large Accelerated Filer (X) ( ) ( ) Accelerated Filer ( ) ( ) ( ) Non-accelerated Filer ( ) (X) (X) Smaller Reporting 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 (X) (X) (X) As of June 28, 2013, Ameren Corporation had 242,634,671 shares of its $0.01 par value common stock outstanding. The aggregate market value of these shares of common stock (based upon the closing price of the common stock on the New York Stock Exchange on June 28, 2013) held by nonaffiliates was $8,356,338,069. The shares of common stock of the other registrants were held by Ameren Corporation as of June 28, 2013. The number of shares outstanding of each registrant’s classes of common stock as of January 31, 2014, was as follows: Ameren Corporation Union Electric Company Ameren Illinois Company Common stock, $0.01 par value per share: 242,634,671 Common stock, $5 par value per share, held by Ameren Corporation (parent company of the registrant): 102,123,834 Common stock, no par value, held by Ameren Corporation (parent company of the registrant): 25,452,373 DOCUMENTS INCORPORATED BY REFERENCE 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 2014 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. TABLE OF CONTENTS GLOSSARY OF TERMS AND ABBREVIATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Forward-looking Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PART I Item 1. Item 1A. Item 1B. Item 2. Item 3. Item 4. Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Business Segments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rates and Regulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission and Supply of Electric Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power Generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural Gas Supply for Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industry Issues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating Statistics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Available Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Risk Factors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unresolved Staff Comments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mine Safety Disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Executive Officers of the Registrants (Item 401(b) of Regulation S-K) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PART II Item 5. Item 6. Item 7. Item 7A. Item 8. Item 9. Item 9A. Item 9B. PART III Item 10. Item 11. Item 12. Item 13. Item 14. Market for Registrants’ Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 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 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effects of Inflation and Changing Prices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Selected Quarterly Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Changes in and Disagreements with Accountants on Accounting and Financial Disclosure . . . . . . . . . . Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 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 Accounting Fees and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PART IV Item 15. Exhibits and Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . EXHIBIT INDEX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Page 1 4 5 5 6 6 10 11 13 14 14 16 16 23 24 25 26 26 28 30 30 31 32 47 59 62 62 65 66 70 154 154 155 155 155 156 156 157 157 158 162 165 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. 2010 Illinois Credit Agreement – Ameren’s and Ameren Illinois’ $800 million multiyear senior unsecured credit agreement, which was terminated on November 14, 2012. 2010 Missouri Credit Agreement – Ameren’s and Ameren Missouri’s $800 million multiyear senior unsecured credit agreement, which was terminated on November 14, 2012. 2012 Credit Agreements – The 2012 Illinois Credit Agreement and the 2012 Missouri Credit Agreement, collectively. 2012 Illinois Credit Agreement – Ameren’s and Ameren Illinois’ $1.1 billion multiyear senior unsecured credit agreement, which expires on November 14, 2017. 2012 Missouri Credit Agreement – Ameren’s and Ameren Missouri’s $1 billion multiyear senior unsecured credit agreement, which expires on November 14, 2017. AER – Ameren Energy Resources Company, LLC, an Ameren Corporation subsidiary that consisted of non-rate- regulated operations. On December 2, 2013, AER contributed substantially all of its assets and liabilities, including its ownership interests in Genco, AERG, and Marketing Company, to New AER. Medina Valley was distributed from AER to Ameren on March 14, 2013. AERG – Ameren Energy Resources Generating Company, a former AER subsidiary that operated a merchant electric generation business in Illinois. On December 2, 2013, AERG was included in the divestiture of New AER to IPH. After the divestiture of New AER was completed, AERG became Illinois Power Resources Generating, LLC. 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 or AIC – Ameren Illinois Company, an Ameren Corporation subsidiary that operates a rate- regulated electric and natural gas transmission and distribution business in Illinois, doing business as Ameren Illinois. Ameren Illinois is also defined as a financial reporting segment. Ameren Illinois Merger – On October 1, 2010, CILCO and IP merged with and into CIPS, with the surviving corporation renamed Ameren Illinois Company. Ameren Missouri or AMO – Union Electric Company, an Ameren Corporation subsidiary that operates a rate- regulated electric generation, transmission and distribution business, and a rate-regulated natural gas transmission and distribution business in Missouri, doing business as Ameren Missouri. Ameren Missouri is also defined as a financial reporting segment. Ameren Services – Ameren Services Company, an Ameren Corporation subsidiary that provides support services to Ameren and its subsidiaries. AMIL – The MISO balancing authority area operated by Ameren, which includes the load of Ameren Illinois and ATXI. AMMO – The MISO balancing authority area operated by Ameren, which includes the load and energy centers of Ameren Missouri. ARO – Asset retirement obligations. ATXI – Ameren Transmission Company of Illinois, an Ameren Corporation subsidiary that is engaged in the construction and operation of electric transmission assets. Baseload – The minimum amount of electric power delivered or required over a given period of time at a steady rate. 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. CAIR – Clean Air Interstate Rule. Capacity factor – A percentage measure that indicates how much of an energy center’s capacity was used during a specific period. CCR – Coal combustion residuals. CILCO – Central Illinois Light Company, a former Ameren Corporation subsidiary that operated a rate-regulated electric transmission and distribution business, and a rate- regulated natural gas transmission and distribution business, all in Illinois, before the Ameren Illinois Merger. CILCORP – CILCORP Inc., a former Ameren Corporation subsidiary that operated as a holding company for CILCO and its merchant generation subsidiary. On March 4, 2010, CILCORP merged with and into Ameren. CIPS – Central Illinois Public Service Company, an Ameren Corporation subsidiary, renamed Ameren Illinois Company at the effective date of the Ameren Illinois Merger, which operates a rate-regulated electric and natural gas transmission and distribution business, all in Illinois. CO2 – Carbon dioxide. COL – Nuclear energy center combined construction and operating license. Cole County Circuit Court – Circuit Court of Cole County, Missouri. Cooling degree-days – The summation of positive differences between the mean 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. CSAPR – Cross-State Air Pollution Rule. CT – Combustion turbine electric energy center used primarily for peaking capacity. DOE – Department of Energy, a United States government agency. DRPlus – Ameren Corporation’s dividend reinvestment and direct stock purchase plan. Dekatherm – One million Btus of natural gas. Dynegy – Dynegy Inc. 1 EEI – Electric Energy, Inc., an 80%-owned Genco subsidiary that operates merchant electric generation energy centers and FERC-regulated transmission facilities in Illinois. On December 2, 2013, Genco’s ownership interest in EEI was included in the divestiture of New AER to IPH. Entergy – Entergy Arkansas, Inc. EPA – Environmental Protection Agency, a United States government agency. Equivalent availability factor – A measure that indicates the percentage of time an energy center was available for service during a period. ERISA – Employee Retirement Income Security Act of 1974, as amended. Exchange Act – Securities Exchange Act of 1934, as amended. FAC – Fuel adjustment clause, a fuel and purchased power cost recovery mechanism that allows Ameren Missouri to recover, through customer rates, 95% of changes in net energy costs greater or less than the amount set in base rates without a traditional rate proceeding, subject to MoPSC prudence reviews. Net energy cost includes fuel (coal, coal transportation, natural gas for generation, and nuclear), certain fuel additives, emission allowances, purchased power costs, transmission costs and revenues, and MISO costs and revenues, net of off-system sales revenues. FASB – Financial Accounting Standards Board, a rulemaking organization that establishes financial accounting and reporting standards in the United States. FERC – Federal Energy Regulatory Commission, a United States government agency. Fitch – Fitch Ratings, a credit rating agency. FTRs – Financial transmission rights, financial instruments that specify whether the holder shall pay or receive compensation for certain congestion-related transmission charges between two designated points. GAAP – Generally accepted accounting principles in the United States of America. Genco – Ameren Energy Generating Company, a former AER subsidiary that operated a merchant electric generation business in Illinois and holds an 80% ownership interest in EEI. On December 2, 2013, Genco was included in the divestiture of New AER to IPH. After the New AER divestiture was completed, Genco became Illinois Power Generating Company. Heating degree-days – The summation of negative differences between the mean daily temperature and a 65- degree Fahrenheit base. This statistic is useful as an indicator of demand for electricity and natural gas for winter space heating by residential and commercial customers. IBEW – International Brotherhood of Electrical Workers, a labor union. 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 delivery service rates. By its election to participate in this regulatory framework, Ameren Illinois is required to make incremental capital expenditures to modernize its electric distribution system, meet performance standards, and create jobs in Illinois, among other things. IP – Illinois Power Company, a former Ameren Corporation subsidiary that operated a rate-regulated electric and natural gas transmission and distribution business, all in Illinois, before the Ameren Illinois Merger. 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. IPH – Illinois Power Holdings, LLC, an indirect wholly owned subsidiary of Dynegy. IRS – Internal Revenue Service, a United States government agency. ISRS – Infrastructure system replacement surcharge, which is a cost recovery mechanism that allows Ameren Missouri to recover natural gas infrastructure replacement costs from utility customers without a traditional rate proceeding. IUOE – International Union of Operating Engineers, a labor union. Kilowatthour – A measure of electricity consumption equivalent to the use of 1,000 watts of power over one hour. LIUNA – Laborers’ International Union of North America, a labor union. Marketing Company – Ameren Energy Marketing Company, a former AER subsidiary that marketed power for Genco, AERG, and EEI. Marketing Company was included in the divestiture of New AER to IPH on December 2, 2013. After the divestiture of New AER was completed, Marketing Company became Illinois Power Marketing Company. MATS – Mercury and Air Toxics Standards. Medina Valley – AmerenEnergy Medina Valley Cogen, LLC, an Ameren Corporation subsidiary. Previously, this company owned a 40-megawatt natural gas-fired electric energy center that was sold in February 2012. This company was distributed from AER to Ameren on March 14, 2013. MEEIA – Missouri Energy Efficiency Investment Act, a Missouri law that allows electric utilities to recover costs related to MoPSC-approved energy efficiency programs. Megawatthour or MWh – One thousand kilowatthours. Merchant Generation – A financial reporting segment that prior to the divestiture of New AER to IPH on December 2, 2013, consisted primarily of the operations of AER, including Genco, AERG, Marketing Company and, through March 13, 2013, Medina Valley. MGP – Manufactured gas plant. MIEC – Missouri Industrial Energy Consumers. MISO – Midcontinent Independent System Operator, Inc., an RTO. 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. 2 Moody’s – Moody’s Investors Service Inc., a credit rating agency. MoOPC – Missouri Office of Public Counsel. MoPSC – Missouri Public Service Commission, a state agency that regulates Missouri utility businesses, including Ameren Missouri. MPS – Multi-Pollutant Standard, a compliance alternative under Illinois law covering reductions in emissions of SO2, NOx, and mercury, which Genco, EEI, and AERG elected in 2006. MTM – Mark-to-market. MW – Megawatt. Native load – End-use retail customers whom we are obligated to serve by statute, franchise, contract, or other regulatory requirement. NERC – North American Electric Reliability Corporation. New AER – New Ameren Energy Resources Generating Company, LLC, a limited liability company formed as a direct wholly owned subsidiary of AER. New AER, acquired by IPH on December 2, 2013, included substantially all of the assets and liabilities of AER, except for certain assets and liabilities retained by Ameren. After Ameren’s divestiture of New AER to IPH was completed, this entity became Illinois Power Resources, LLC. NO2 – Nitrogen dioxide. NOx – Nitrogen oxides. Noranda – Noranda Aluminum, Inc. NPNS – Normal purchases and normal sales. NRC – Nuclear Regulatory Commission, a United States government agency. NSPS – New Source Performance Standards, a provision 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. NWPA – Nuclear Waste Policy Act of 1982, as amended. NYMEX – New York Mercantile Exchange. NYSE – New York Stock Exchange, Inc. OATT – Open Access Transmission Tariff. OCI – Other comprehensive income (loss) as defined by GAAP. Off-system sales revenues – Revenues from other than native load sales, including wholesale sales beginning with the July 31, 2011 effective date of the MoPSC’s 2011 electric rate order. OTC – Over-the-counter. PGA – Purchased Gas Adjustment tariffs, which permit prudently incurred natural gas costs to be recovered directly from utility customers without a traditional rate proceeding. PJM – PJM Interconnection LLC. PUHCA 2005 – The Public Utility Holding Company Act of 2005. Rate base – The net value of property on which a public utility is permitted to earn an allowed rate of return. Regulatory lag – The effect of adjustments to retail electric and natural gas rates being based on historic cost and sales volume levels. Rate increase requests, in traditional rate case proceedings, 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 behind changing costs and sales volume levels when based on historical periods. Revenue requirement – The cost of providing utility service to customers, which is calculated as the sum of a utility’s recoverable operating and maintenance expenses, depreciation and amortization expense, taxes, and an allowed return on investment. RFP – Request for proposal. Rockland Capital – Rockland Capital, LLC together with the special purpose entity affiliated with and formed by Rockland Capital, LLC that acquired the Elgin, Gibson City, and Grand Tower gas-fired energy centers. RTO – Regional transmission organization. S&P – Standard & Poor’s Ratings Services, 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. SO2 – Sulfur dioxide. Stoddard County Circuit Court – Circuit Court of Stoddard County, Missouri. UA – United Association of Plumbers and Pipefitters, a labor union. Westinghouse – Westinghouse Electric Company. 3 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, strategies, 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 under Risk Factors 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, including changes in regulatory policies and ratemaking determinations, such as the complaint cases filed by Noranda and 37 residential customers with the MoPSC in February 2014; the outcome of Ameren Illinois’ appeal of the ICC’s electric rate order issued in December 2013; Ameren Illinois’ request for rehearing of a July 2012 FERC order regarding the inclusion of acquisition premiums in its transmission rates; and future regulatory, judicial, or legislative actions that seek to change regulatory recovery mechanisms; the effect of Ameren Illinois participating in a performance-based formula ratemaking process under the IEIMA, including the direct relationship between Ameren Illinois’ return on common equity and the 30- year United States Treasury bond yields, the related financial commitments required by the IEIMA, and the resulting uncertain impact on the financial condition, results of operations, and liquidity of Ameren Illinois; the effects of Ameren Illinois’ expected participation, beginning in 2015, in the regulatory framework provided by the state of Illinois’ Natural Gas Consumer, Safety and Reliability Act, which allows for the use of a rider to recover costs of certain natural gas infrastructure investments made between rate cases; the effects of, or changes to, the Illinois power procurement process; the effects of increased competition in the future due to, among other things, deregulation of certain aspects of our business at either the state or federal levels and the implementation of deregulation; changes in laws and other governmental actions, including monetary, fiscal, and tax policies; the effects on demand for our services resulting from technological advances, including advances in energy efficiency and distributed generation sources, which generate electricity at the site of consumption; increasing capital expenditure and operating expense requirements and our ability to timely recover these costs; 4 ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ the cost and availability of fuel such as coal, natural gas, and enriched uranium used to produce electricity; the cost and availability of purchased power and natural gas for distribution; and the level and volatility of future market prices for such commodities, including our ability to recover the costs for such commodities; the effectiveness of our risk management strategies and the use of financial and derivative instruments; business and economic conditions, including their impact on interest rates, bad debt expense, and demand for our products; disruptions of the capital markets, deterioration in credit metrics of the Ameren Companies, or other events that may make the Ameren Companies’ access to necessary capital, including short-term credit and liquidity, impossible, more difficult, or more costly; our assessment of our liquidity; the impact of the adoption of new accounting guidance and the application of appropriate technical accounting rules and guidance; actions of credit rating agencies and the effects of such actions; the impact of weather conditions and other natural phenomena on us and our customers; the impact of system outages; generation, transmission, and distribution asset construction, installation, performance, and cost recovery; the effects of our increasing investment in electric transmission projects and uncertainty as to whether we will achieve our expected returns in a timely fashion, if at all; the extent to which Ameren Missouri prevails in its claims against insurers in connection with its Taum Sauk pumped-storage hydroelectric energy center incident; the extent to which Ameren Missouri is permitted by its regulators to recover in rates the investments it made in connection with additional nuclear generation at its Callaway energy center; operation of Ameren Missouri’s Callaway energy center, including planned and unplanned outages, and decommissioning costs; the effects of strategic initiatives, including mergers, acquisitions and divestitures, and any related tax implications; the impact of current environmental regulations on utilities and power generating companies and new, more stringent or changing requirements, including those related to greenhouse gases, other emissions and discharges, cooling water intake structures, CCR, and energy efficiency, that are enacted over time and that could limit or terminate the operation of certain of our energy centers, increase our costs, result in an impairment of our assets, result in sales of 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 portfolio requirements in Missouri; ‰ ‰ ‰ labor disputes, workforce reductions, future wage and employee benefits costs, including changes in discount rates and returns on benefit plan assets; the inability of our counterparties to meet their obligations with respect to contracts, credit agreements, and financial instruments; the cost and availability of transmission capacity for the energy generated by Ameren’s and Ameren Missouri’s energy centers or required to satisfy energy sales made by Ameren or Ameren Missouri; the inability of Dynegy and IPH to satisfy their indemnity and other obligations to Ameren in connection with the divestiture of New AER to IPH; legal and administrative proceedings; and acts of sabotage, war, terrorism, cyber attacks or intentionally disruptive acts. ‰ ‰ ‰ 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, headquartered in St. Louis, Missouri, is a As a result of the transaction agreement with IPH and public utility holding company under PUHCA 2005, administered by FERC. Ameren was formed in 1997 by the merger of Ameren Missouri and CIPSCO Inc. Ameren acquired CILCORP in 2003 and IP in 2004. Ameren’s primary assets are its equity interests in its subsidiaries, including Ameren Missouri and Ameren Illinois. Ameren’s subsidiaries are separate, independent legal entities with separate businesses, assets, and liabilities. Dividends on Ameren’s common stock and the payment of other expenses by Ameren depend on distributions made to it by its subsidiaries. Below is a summary description of Ameren Missouri and Ameren Illinois. 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 transmission and distribution business in Missouri. Ameren Illinois operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. Ameren has various other subsidiaries responsible for activities such as the provision of shared services. Ameren also has a subsidiary, ATXI, that operates a FERC rate- regulated electric transmission business and is developing the Illinois Rivers project. The Illinois Rivers project is a MISO-approved project to build a 345-kilovolt line from western Indiana across the state of Illinois to eastern Missouri at an estimated cost of $1.1 billion. On March 14, 2013, Ameren entered into a transaction agreement to divest New AER to IPH. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. On January 31, 2014, Medina Valley completed its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information. Ameren’s plan to sell its Elgin, Gibson City, and Grand Tower gas-fired energy centers, Ameren determined that New AER and the gas-fired energy centers qualified for discontinued operations presentation beginning March 14, 2013. In addition, as of December 2, 2013, Ameren abandoned the Meredosia and Hutsonville energy centers upon the completion of the divestiture of New AER to IPH. Ameren is prohibited from operating these energy centers through December 31, 2020, as a provision of the Illinois Pollution Control Board’s November 2013 order granting IPH a variance of the MPS. As a result, Ameren determined that the Meredosia and Hutsonville energy centers qualified for discontinued operations presentation as of December 2, 2013. The Meredosia and Hutsonville energy centers ceased operations at December 31, 2011, and therefore 2011 was the last year those energy centers had a material effect on Ameren’s consolidated financial statements. As a result of these events, Ameren has segregated New AER’s and the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers’ operating results, assets, and liabilities and presented them separately as discontinued operations for all periods presented in this report. Unless otherwise stated, the following sections within Part I, Item 1, of this report exclude discontinued operations for all periods presented. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information regarding that presentation. The following table presents our total employees at December 31, 2013: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Services and Other . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,932 3,133 1,462 8,527 As of January 1, 2014, the IBEW, the IUOE, the LIUNA, and the UA labor unions collectively represented about 56% of Ameren’s total employees. They represented 64% of the employees at Ameren Missouri and 61% at Ameren Illinois. The collective bargaining agreements have two- to six-year terms, and expire between 2015 and 2017. 5 For additional information about the development of our businesses, our business operations, and factors affecting our operations and financial position, see Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report and Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. BUSINESS SEGMENTS Ameren has two reportable segments: Ameren Missouri and Ameren Illinois. See Note 17 – Segment Information under Part II, Item 8, of this report for additional information on reporting segments. RATES AND REGULATION Rates regulatory staff knowledge and experience, customer intervention, economic conditions, public policy, and social and political views. Decisions made by these governmental entities regarding rates are largely outside of our control. These decisions, as well as the regulatory lag involved in filing and getting new rates approved, could have a material impact on the results of operations, financial position, and liquidity of Ameren, Ameren Missouri and Ameren Illinois. The extent of the regulatory lag varies for each of Ameren’s electric and natural gas jurisdictions, with our FERC- regulated electric jurisdictions experiencing the least amount of regulatory lag. The effects of regulatory lag are mitigated through a variety of means including the use of a future test year, the implementation of trackers and riders, the deferral of depreciation for assets not yet included in rate base, and by regulatory frameworks that include annual revenue requirement reconciliations. The rates that Ameren Missouri, Ameren Illinois and The ICC regulates rates and other matters for Ameren 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, in large part, by governmental entities, including the MoPSC, the ICC, and FERC. Decisions by these entities are influenced by many factors, including the cost of providing service, the prudency of expenditures, the quality of service, Illinois and the ICC regulates non-rate utility matters for ATXI. ATXI does not have retail distribution customers, and therefore the ICC does not have authority to regulate its rates. The MoPSC regulates rates and other matters for Ameren Missouri. FERC regulates Ameren Missouri, Ameren Illinois and ATXI as to their ability to charge market-based rates for the wholesale sale and transmission of energy in interstate commerce and various other matters discussed below under General Regulatory Matters. The following table summarizes, by rate jurisdiction, the rate orders in effect for customer billings for each of Ameren’s rate-regulated utilities as of January 1, 2014. Allowed Return on Equity Percent of Common Equity Rate Base (in billions) Portion of Ameren’s 2013 Operating Revenues(a) Regulator Ameren Missouri Electric service(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas delivery service(d) MoPSC MoPSC Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . Electric distribution delivery service(f) Natural gas delivery service(g) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric transmission delivery service(h) . . . . . . . . . . . . . . . . . . . . . . . . ICC ICC FERC 9.8% (e) 8.7% 9.1% 12.38% 52.3% 52.9% 51.0% 51.7% 55.2% ATXI Electric transmission delivery service(h) . . . . . . . . . . . . . . . . . . . . . . . . FERC 12.38% 56.0% $6.8 $0.2(e) $2.0 $1.1 $0.7 $0.2 58% 3% 23% 14% 2% (i) (a) Includes pass-through costs recovered from customers, such as purchased power for electric distribution delivery service and gas purchased for resale for natural gas delivery service. (b) Ameren Missouri electric generation, transmission, and delivery service rates are bundled together and charged to retail customers under a combined electric service rate. (c) Based on MoPSC’s December 2012 rate order, which became effective on January 2, 2013. (d) Based on MoPSC’s January 2011 rate order, which became effective on February 20, 2011. (e) Ameren Missouri’s last natural gas rate order did not specify the allowed return on equity or rate base. (f) Based on the ICC’s December 2013 rate order, which became effective on January 1, 2014. The December 2013 rate order was based on 2012 recoverable costs, expected net plant additions for 2013, and the monthly yields during 2012 of the 30-year United States treasury bonds plus 580 basis points. Ameren Illinois’ 2014 electric distribution delivery service revenues will be based on its 2014 actual recoverable costs, rate base, and return on common equity, as calculated under the IEIMA’s performance-based formula ratemaking framework. (g) Based on the ICC’s December 2013 rate order, which became effective on January 1, 2014. The rate order was based on a 2014 future test year. (h) Transmission rates are updated and become effective each January using a company-specific, forward-looking rate formula framework, which is based on that year’s forecasted information. Less than 1%. (i) 6 Ameren Missouri Electric Ameren Missouri’s electric operating revenues are subject to regulation by the MoPSC. In December 2012, the MoPSC issued an order approving rates for electric service based on a 9.8% return on equity, a capital structure composed of 52.3% common equity, and a rate base of $6.8 billion. These rates became effective on January 2, 2013. If certain criteria are met, Ameren Missouri’s electric rates may be adjusted without a traditional rate proceeding. The FAC permits Ameren Missouri to recover, through customer rates, 95% of changes in net energy costs greater than or less than the amount set in base rates without a traditional rate proceeding, subject to prudence reviews. Net energy cost includes fuel, emission allowances, purchased power costs, certain fuel additives, transmission costs and revenues, and MISO costs and revenues, net of off-system sales revenues. Similarly, all of Ameren Missouri’s MEEIA costs, including energy efficiency program costs, projected lost revenues, and potential incentive awards, are recovered through a rider that may be adjusted without a traditional rate proceeding. In addition to the FAC and the MEEIA recovery mechanisms, Ameren Missouri employs other cost recovery mechanisms including a vegetation management and infrastructure inspection cost tracker, a pension and postretirement benefit cost tracker, an uncertain tax position tracker, a renewable energy standards cost tracker, solar rebate program tracker, and a storm cost tracker. Each of these trackers allows Ameren Missouri to record the difference between the level of incurred costs under GAAP and the level of such costs built into rates as a regulatory asset or regulatory liability, which will be included in rates in a future rate order. FERC regulates the rates charged and the terms and conditions for electric transmission services. Because Ameren Missouri is a member of MISO, its transmission rate is calculated in accordance with the MISO OATT. The transmission rate is updated in June of each year; it is based on Ameren Missouri’s filings with FERC. This rate is not directly charged to Missouri retail customers, because in Missouri the MoPSC includes transmission-related costs and revenues in setting bundled retail rates. As discussed above, Ameren Missouri transmission revenues, as well as certain transmission costs paid to MISO for transmission services, are included in the FAC. Natural Gas Ameren Missouri’s natural gas operating revenues are subject to regulation by the MoPSC. The last natural gas delivery service rate order was issued by the MoPSC in January 2011. If certain criteria are met, Ameren Missouri’s natural gas rates may be adjusted without a traditional rate proceeding. PGA clauses permit prudently incurred natural gas costs to be passed directly to customers. The ISRS also permits certain prudently incurred natural gas infrastructure replacement costs to be recovered from customers on a more timely basis between rate cases. The return on equity to be used by Ameren Missouri for purposes of the ISRS tariff filing is 10%. An ISRS tariff was approved and became effective in October 2013 for the recovery of eligible infrastructure system replacement investments made from January 2011 through May 2013, which resulted in a $1 million annual increase in rates. For additional information on Missouri 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, and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. Ameren Illinois Electric Ameren Illinois’ electric operating revenues, are subject to either ICC or FERC regulation. Ameren Illinois electric distribution delivery service is regulated by the ICC, while its electric transmission delivery service is regulated by FERC. In 2013, Ameren Illinois’ electric distribution delivery service comprised 90% of its total electric operating revenues, with the remainder of its electric operating revenues related to electric transmission delivery service. Under Illinois law, all electric customers in Illinois may choose their own electric energy provider. However, Ameren Illinois is required to serve as the provider of last resort (POLR) for electric customers within its territory who have not chosen an alternative retail electric supplier. Ameren Illinois’ obligation to provide POLR electric service varies by customer size. Ameren Illinois is not required to offer fixed-priced electric service to customers with electric demands of 400 kilowatts or greater, as the market for service to this group of customers has been declared competitive. Power and related procurement costs incurred by Ameren Illinois are passed directly to its customers through a cost recovery mechanism. Ameren Illinois participates in the performance-based formula ratemaking process established pursuant to the IEIMA. The IEIMA was designed to provide for the recovery of actual costs of electric delivery service that are prudently incurred and to reflect the utility’s actual regulated capital structure through a formula for calculating the return on equity component of the cost of capital. The return on equity component of the formula rate is equal to the average for the calendar year of the monthly yields of 30- year United States treasury bonds plus 580 basis points. Ameren Illinois’ actual return on equity relating to electric delivery service is subject to a collar adjustment on earnings in excess of 50 basis points greater than or less than its allowed return. The IEIMA provides for an annual reconciliation of the revenue requirement necessary to reflect the actual costs incurred in a given year with the revenue requirement in effect for that year, including an 7 allowed return on equity. This annual revenue reconciliation, along with the collar adjustment, if necessary, will be collected from or refunded to customers in a subsequent year. Ameren Illinois is also subject to performance standards under the IEIMA. Failure to achieve the standards would result in a reduction in the company’s allowed return on equity calculated under the formula. The performance standards include improvements in service reliability to reduce both the frequency and duration of outages, reduction in the number of estimated bills, reduction of consumption on inactive meters, and a reduction in uncollectible accounts expense. The IEIMA provides for return on equity penalties totaling up to 30 basis points in 2013 through 2015, 34 basis points in 2016 through 2018, and 38 basis points in 2019 through 2022 if the performance standards are not met. The formula ratemaking process is effective until the end of 2017, but could be extended by the Illinois General Assembly for an additional five years. The formula ratemaking process would also terminate if the average residential rate were to increase by more than 2.5% annually from June 2011 through May 2014. The average residential rate includes generation service, which is outside of Ameren Illinois’ control, as Ameren Illinois is required to purchase all of its power through procurement processes administered by the IPA. Ameren Illinois does not expect the annual increase in its average residential rate to exceed 2.5% through May 2014. Between 2012 and 2021, Ameren Illinois is required, pursuant to the IEIMA, to invest $625 million in capital projects incremental to Ameren Illinois’ average electric delivery service capital projects for calendar years 2008 through 2010 to modernize its distribution system. Through 2013, Ameren Illinois invested $61 million in IEIMA capital projects toward its $625 million requirement. Such investments are expected to encourage economic development and to create an estimated 450 additional jobs within Illinois. Ameren Illinois is subject to monetary penalties if 450 additional jobs are not created during the peak program year. Ameren Illinois employs cost recovery mechanisms for power procurement, energy efficiency programs, certain environmental costs, and bad debt expense not recovered in base rates. Ameren Illinois also has a tariff rider to recover the costs of certain asbestos-related litigation claims. Because Ameren Illinois is a member of MISO, its transmission rate is calculated in accordance with the MISO OATT. Currently, the FERC-allowed return on common equity in the ratemaking formula for MISO transmission owners is 12.38%. Ameren Illinois has received FERC approval to use a company-specific, forward-looking rate formula framework in setting its transmission rates. These forward-looking rates are updated each January with forecasted information, with a subsequent reconciliation during the year to adjust for the actual revenue requirement and actual billed revenues, which will be used to adjust billing rates in a subsequent year. In Illinois, the AMIL pricing zone rate is charged directly to wholesale customers and alternative retail electric suppliers, which serve unbundled retail load. For Ameren Illinois retail customers who have not chosen an alternative retail electric supplier, the AMIL transmission rate, and other MISO-related costs are collected through a rider mechanism in Ameren Illinois’ retail distribution tariffs. Natural Gas Ameren Illinois’ natural gas operating revenues are subject to regulation by the ICC. In December 2013, the ICC issued a rate order that approved an increase in revenues for natural gas delivery service of $32 million. The revenue increase was based on a 9.1% return on equity, a capital structure composed of 51.7% common equity, and a rate base of $1.1 billion. The rate order was based on a 2014 future test year. The rate changes became effective January 1, 2014. Ameren Illinois expects to file an appeal of the ICC’s order to the Appellate Court in March 2014. If certain criteria are met, Ameren Illinois’ natural gas rates may be adjusted without a traditional rate proceeding. PGA clauses permit prudently incurred natural gas costs to be passed directly to customers. Also, Ameren Illinois employs cost recovery mechanisms for energy efficiency programs, certain environmental costs, and bad debt expense not recovered in base rates. In July 2013, Illinois enacted the Natural Gas Consumer, Safety and Reliability Act, which encourages Illinois natural gas utilities to accelerate modernization of the state’s natural gas infrastructure and provides additional ICC oversight of natural gas utility performance. The law allows natural gas utilities the option to file for, and requires the ICC to approve, a rate rider mechanism to recover costs of certain natural gas infrastructure investments made between rate cases. The law does not require a minimum level of investment. Ameren Illinois expects to begin including investments under this regulatory framework in 2015. Ameren Illinois’ decision to accelerate modernization of its natural gas infrastructure under this regulatory framework is dependent upon multiple considerations, including the allowed return on equity under this regulatory framework compared with other Ameren and Ameren Illinois investment options. ATXI Similar to Ameren Illinois, ATXI is a member of MISO, and its transmission rate is calculated in accordance with the MISO OATT. Currently, the FERC-allowed return on common equity in the ratemaking formula for MISO transmission owners is 12.38%. ATXI has received FERC approval to use a company-specific, forward-looking rate formula framework in setting its transmission rates. These forward-looking rates are updated each January with forecasted information, with a subsequent reconciliation during the year to adjust for the actual revenue requirement 8 and actual billed revenues, which will be used to adjust billing rates in a subsequent year. Additionally, FERC has approved transmission rate incentives relating to the three MISO-approved multi-value projects discussed below, which allow construction work in progress to be included in rate base, thereby improving cash flows. The three MISO-approved multi-value projects being developed by ATXI are the Illinois Rivers, Spoon River, and Mark Twain projects. The first project, Illinois Rivers, involves the construction of a 345-kilovolt line from western Indiana across the state of Illinois to eastern Missouri. ATXI obtained a certificate of public convenience and necessity and project approval from the ICC for the entire Illinois Rivers project. A full range of construction activities for the Illinois Rivers project is scheduled in 2014. The first sections of the Illinois Rivers project are expected to be completed in 2016. The last section of this project is expected to be completed in 2019. The Spoon River project in northwest Illinois and the Mark Twain project in northeast Missouri are the other two projects approved by MISO. These two projects are expected to be completed in 2018. The total investment in these three projects is expected to be more than $1.4 billion through 2019. For additional information on Illinois 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 and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. General Regulatory Matters Ameren Missouri and Ameren Illinois 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 with a value in excess of $10 million. In addition, these Ameren utilities must receive authorization from the applicable state public utility regulatory agency to issue stock and long-term debt securities (with maturities of more than 12 months) 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 FERC, to ensure the reliability of the bulk power electric system. These standards are developed and enforced by NERC pursuant to authority given to it by FERC. If Ameren or its subsidiaries were found not to be in compliance with any of these mandatory reliability standards, they could incur substantial monetary penalties and other sanctions. Under PUHCA 2005, FERC and any state public utility regulatory agency may access books and records of Ameren and its subsidiaries that are determined to be relevant to costs incurred by Ameren’s rate-regulated subsidiaries with respect to jurisdictional rates. PUHCA 2005 also permits the MoPSC and the ICC to request that FERC review cost allocations by Ameren Services to other Ameren companies. Operation of Ameren Missouri’s Callaway energy center is subject to regulation by the NRC. Its facility operating license expires in October 2024. In December 2011, Ameren Missouri submitted a license extension application to the NRC to extend the energy center’s operating license to 2044. There is no date by which the NRC must act on this relicensing request. Ameren Missouri’s Osage hydroelectric energy center and Ameren Missouri’s Taum Sauk pumped-storage hydroelectric energy center, as licensed projects under the Federal Power Act, are subject to FERC regulations affecting, among other things, the general operation and maintenance of the projects. The license for Ameren Missouri’s Osage hydroelectric energy center expires in March 2047. In June 2008, Ameren Missouri filed a relicensing application with FERC to operate its Taum Sauk pumped-storage hydroelectric energy center for another 40 years. The existing FERC license expired on June 30, 2010. In July 2010, Ameren Missouri received a license extension that allows Taum Sauk to continue operations until FERC issues a new license. FERC is reviewing the relicensing application. A FERC order is expected in 2014. Ameren Missouri cannot predict the ultimate outcome of the order. Ameren Missouri’s Keokuk energy center and its dam in 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 10 – Callaway Energy Center, and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. Environmental Matters Certain of our operations are subject to federal, state, and local environmental statutes and regulations relating to the safety and health of personnel, the public, and the environment. These environmental statutes and regulations include requirements relating to identification, generation, storage, handling, transportation, disposal, recordkeeping, labeling, reporting, and emergency response in connection with hazardous and toxic materials; safety and health standards; and environmental protection requirements, including standards and limitations relating to the discharge of air and water pollutants and the management of waste and byproduct materials. Failure to comply with those statutes or regulations could have material adverse effects 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 statutes and regulations that currently apply to our operations. 9 The EPA is developing environmental regulations that will have a significant impact on the electric utility industry. Over time, compliance with these regulations could be particularly costly for certain companies, including Ameren Missouri, that operate coal-fired energy centers. Significant new rules proposed or promulgated include the regulation of CO2 emissions from new energy centers; revised national ambient air quality standards for ozone, fine particulates, SO2, and NOx emissions; the CSAPR, which would have required further reductions of SO2 emissions and NOx emissions from energy centers; a regulation governing management of CCR and coal ash impoundments; the MATS, which require reduction of emissions of mercury, toxic metals, and acid gases from energy centers; revised NSPS for particulate matter, SO2, and NOx emissions from new sources; new effluent standards applicable to waste water discharges from energy centers and new regulations under the Clean Water Act that could require significant capital expenditures, such as modifications to water intake structures or new cooling towers at our energy centers. The EPA is expected to propose CO2 standards for existing fossil fuel-fired electric generation units in the future. These new and proposed regulations, if adopted, may be challenged through litigation, so their ultimate implementation, as well as the timing of any such implementation, is uncertain. Although many details of these future regulations are unknown, the combined effects of the new and proposed environmental regulations may result in significant capital expenditures and increased operating costs over the next five to ten years for Ameren and Ameren Missouri. Compliance with these environmental laws and regulations could be prohibitively expensive or could result in the closure or alteration of the operation of some of our energy centers. Ameren and Ameren Missouri would expect these costs to be recoverable through rates, but the nature and timing of costs, as well as the applicable regulatory framework, could result in regulatory lag. For additional discussion of environmental matters, including NOx, SO2, and mercury emission reduction requirements, remediation efforts, and a discussion of the EPA’s allegations of violations of the Clean Air Act and Missouri law in connection with projects at Ameren Missouri’s Rush Island energy center, see Liquidity and Capital Resources in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. TRANSMISSION AND SUPPLY OF ELECTRIC POWER Ameren owns an integrated transmission system that comprises the transmission assets of Ameren Missouri, Ameren Illinois and ATXI. Ameren also operates two balancing authority areas, AMMO (which includes Ameren Missouri’s customers), and AMIL (which includes Ameren Illinois’ customers). During 2013, the peak demand was 8,146 megawatts in AMMO and 8,899 megawatts in AMIL. 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 MISO. Ameren Missouri is authorized by the MoPSC to participate in MISO, subject to certain conditions, through May 2016, including the condition that Ameren Missouri later file a study with the MoPSC that evaluates the costs and benefits of Ameren Missouri’s continued participation in MISO, as it has periodically done since its MISO participation began in 2003. The next study is required to be filed with the MoPSC in November 2015. The Ameren Companies are members of SERC. SERC is responsible for the bulk electric power supply system in all or portions of Missouri, Illinois, Arkansas, Kentucky, Tennessee, North Carolina, South Carolina, Georgia, Mississippi, Alabama, Louisiana, Virginia, Florida, Oklahoma, Iowa, and Texas. As a result of the Energy Policy Act of 2005, owners and operators of the bulk electric power system are subject to mandatory reliability standards promulgated by NERC and its regional entities, such as SERC, which are all enforced by FERC. The Ameren Companies must comply with these standards, which are in place to ensure the reliability of the bulk electric power system. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information. Ameren Missouri Ameren Missouri’s electric supply is obtained primarily from its own generation. Factors that could cause Ameren Missouri to purchase power include, among other things, absence of sufficient owned generation, energy center outages, the fulfillment of renewable energy portfolio requirements, the failure of suppliers to meet their power supply obligations, extreme weather conditions, and the availability of power at a cost lower than the cost of generating it. Ameren Missouri continues to evaluate its longer-term needs for new baseload, including nuclear and peaking electric generation capacity. See Energy Efficiency in this section for information on Ameren Missouri’s energy efficiency programs and associated cost recovery mechanisms. The potential need for new energy center construction is dependent on several key factors, including continuation of energy efficiency programs beyond 2015, load growth, customer participation in energy efficiency programs, and the potential for more stringent environmental regulation of coal-fired energy centers, which could lead to the retirement of current baseload assets or alterations in the manner in which those assets operate. Because of the significant time required to plan, acquire permits for, and build a baseload energy center, Ameren Missouri continues to study future alternatives and is taking steps to preserve options to meet future demand. These steps include evaluating the potential for further energy efficiency programs and evaluating potential sites for natural gas-fired generation. Ameren Missouri is also exploring options to expand renewable generation and further diversify its generation portfolio. Ameren Missouri’s 10 next Integrated Resource Plan filing with the MoPSC is due in October 2014. See also 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 and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. Ameren Illinois Any electric supply purchased by Ameren Illinois for its retail customers comes either through an annual procurement process conducted by the IPA or through markets operated by MISO. The power and related procurement costs incurred by Ameren Illinois are passed directly to its customers through a cost recovery mechanism. The IPA administers an RFP process that procures Ameren Illinois’ expected supply obligation. Since the RFP process began in 2009, the ICC has approved the outcomes POWER GENERATION of multiple electric power procurement RFPs for energy, capacity, and renewable energy credits covering different time periods. Under Illinois law, transmission and distribution service rates are regulated, while electric customers are allowed to purchase power from an alternative retail electric supplier. At December 31, 2013, approximately 768,000 retail customers representing approximately 72% of Ameren Illinois’ annual retail kilowatthour sales had elected to purchase their electricity from alternative retail electric suppliers. Customers who receive electricity from alternative retail electric suppliers continue to pay a delivery charge to Ameren Illinois for the distribution services they receive from Ameren Illinois. See Note 2 – Rate and Regulatory Matters, Note 14 – Related Party Transactions and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for additional information on power procurement in Illinois. The following table presents the source of electric generation, excluding purchased power, for the years ended December 31, 2013, 2012, and 2011: Ameren and Ameren Missouri: Coal Nuclear Natural Gas Renewables(a) Oil 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77% 73 77 19% 24 19 (b) 1 1 3% 2 3 (b) (b) (b) (a) Renewable power generation includes production from Ameren Missouri’s hydroelectric, pumped-storage, and methane gas energy centers, but excludes purchased renewable energy credits. (b) Less than 1% of total fuel supply. The following table presents the cost of fuels for electric generation for the years ended December 31, 2013, 2012, and 2011: Cost of Fuels (dollars per mmbtu) 2013 2012 2011 Ameren and Ameren Missouri: Coal(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2.050 0.942 7.907 $ 1.925 0.964 4.517 $ 1.733 0.750 5.873 Weighted average – all fuels(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1.874 $ 1.743 $ 1.610 (a) Represents the cost of coal and the costs for transportation, which include hedges for railroad diesel fuel surcharges. (b) Represents the cost of natural gas and firm and variable costs for transportation, storage, balancing, and fuel losses for delivery to the energy center. In addition, the fixed costs for firm transportation and firm storage capacity are included in the calculation of fuel cost for the energy centers. (c) Represents all costs for fuels used in our energy centers, to the extent applicable, including coal, nuclear, natural gas, methane gas, oil, propane, tire chips, paint products, and handling. Methane gas, oil, propane, tire chips, and paint products are not individually listed in this table because their use is minimal. Coal Ameren Missouri has agreements in place to purchase a portion of the coal it needs and to transport it to energy centers through 2019. Ameren Missouri expects to enter into additional contracts to purchase coal from time to time. Coal supply agreements for Ameren Missouri have terms of up to six years, and expire between 2014 and 2017. Ameren Missouri has an ongoing need for coal to serve its native load customers, so it pursues a price-hedging strategy consistent with this requirement. Ameren Missouri burned 19 million tons of coal in 2013. See Part II, Item 7A – Quantitative and Qualitative Disclosures About Market Risk of this report for additional information about coal supply contracts. 11 About 98% of Ameren Missouri’s coal is purchased from the Powder River Basin in Wyoming. The remaining coal is typically purchased from the Illinois Basin. Inventory 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. In the past, deliveries from the Powder River Basin have occasionally been restricted because of rail maintenance, weather, and derailments. As of December 31, 2013, coal inventories for Ameren Missouri were about 20% below targeted levels due to flooding and weather-related delivery delays. Disruptions in coal deliveries could cause Ameren Missouri to pursue a strategy that could include reducing sales of power during low-margin periods, buying higher-cost fuels to generate required electricity, and purchasing power from other sources. Nuclear pipeline systems of Panhandle Eastern Pipe Line Company, Trunkline Gas Company, Natural Gas Pipeline Company of America, and Mississippi River Transmission Corporation to transport natural gas to energy centers. In addition to physical transactions, Ameren uses financial instruments, including some in the NYMEX futures market and some in the OTC financial markets, to hedge the price paid for natural gas. Ameren Missouri’s natural gas procurement strategy is designed to ensure reliable and immediate delivery of natural gas to its energy centers. This is accomplished by optimizing transportation and storage options and minimizing cost and price risk through various supply and price-hedging agreements that allow access to multiple gas pools, supply basins, and storage services. As of December 31, 2013, Ameren Missouri had price-hedged about 27% of its expected natural gas supply requirements for generation in 2014. The steps in the process to provide nuclear fuel involve Renewable Energy 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, and the fabrication of the enriched uranium hexafluoride gas into usable fuel assemblies. Ameren Missouri has entered into uranium, uranium conversion, uranium enrichment, and fabrication contracts to procure the fuel supply for its Callaway nuclear energy center. Fuel assemblies for the 2014 fall refueling at Ameren Missouri’s Callaway energy center are scheduled for manufacture and delivery to the energy center during the period May to July 2014. Ameren Missouri also has agreements or inventories to price-hedge approximately 100%, 71%, and 60% of Callaway’s 2014, 2016 and 2017 refueling requirements, respectively. Ameren Missouri has uranium (concentrate and hexafluoride) inventories and supply contracts sufficient to meet all of its uranium and conversion requirements through at least 2018. Ameren Missouri has enriched uranium inventories and enrichment supply contracts sufficient to satisfy enrichment requirements through at least 2018. Fuel fabrication services are under contract through 2014. Ameren Missouri expects to enter into additional contracts to purchase nuclear fuel. The Callaway energy center normally requires refueling at 18-month intervals. The last refueling was completed in May 2013. There is no refueling scheduled for 2015 and 2018. The nuclear fuel markets are competitive, and prices can be volatile; however, we do not anticipate any significant problems in meeting our future supply requirements. Natural Gas Supply for Generation To maintain deliveries to natural gas-fired energy centers throughout the year, especially during the summer peak demand, Ameren Missouri’s portfolio of natural gas supply resources includes firm transportation capacity and firm no-notice storage capacity leased from interstate pipelines. Ameren Missouri primarily uses the interstate Illinois and Missouri have enacted laws requiring electric utilities to include renewable energy resources in their portfolios. Illinois requires renewable energy resources to equal or exceed 2% of the total electricity that each electric utility supplied to its eligible retail customers as of June 1, 2008, with that percentage increasing to 10% by June 1, 2015, and to 25% by June 1, 2025. For the 2013 plan year, Ameren Illinois met its requirement that 8% of its total electricity for eligible retail customers be procured from renewable energy resources. Current forecasts indicate that Ameren Illinois has committed to procure sufficient renewable energy credits under the IPA- administered procurement process to meet the renewable energy portfolio requirement through at least May 2018. In December 2010, Ameren Illinois entered into 20-year agreements with renewable energy suppliers. It began receiving renewable energy credits under these agreements in June 2012. Approximately 63% of the 2014 plan year renewable energy requirement is expected to be met through these agreements. The remaining requirement will be met through IPA procurements, which resulted in contracts that were executed in February 2012 with a term of June 2013 through December 2017. In Missouri, utilities are required to purchase or generate from renewable energy sources electricity equaling at least 2% of native load sales, with that percentage increasing to at least 15% by 2021, subject to a 1% annual limit on customer rate impacts. At least 2% of each renewable energy portfolio requirement must be derived from solar energy. Ameren Missouri expects to satisfy the nonsolar requirement through 2018 with its existing renewable generation, including the Maryland Heights energy center, along with a 15-year 102-megawatt power purchase agreement with a wind farm operator in Iowa that became effective in 2009. The Maryland Heights energy center generates electricity by burning methane gas collected from a landfill. Currently, Ameren Missouri is meeting the solar energy requirement through the purchase 12 of solar-generated renewable energy credits and generation from solar panels installed on Ameren’s St. Louis headquarters. In January 2014, Ameren Missouri announced its plans to build a solar energy center which will generate 5 megawatts of solar power. Construction is expected to begin in the spring of 2014, and delivery of power to customers is expected by the end of 2014. In 2013, Ameren Missouri purchased or generated about 5% of its native load sales from renewable energy resources, meeting its requirements. Under the same Missouri statute requiring utilities to purchase or generate energy from renewable sources, Ameren Missouri is required to have a rebate program to provide an incentive for customers to install solar generation on their premises. In accordance with the statute and a 2013 MoPSC order, Ameren Missouri is required to provide $92 million of solar rebates by 2020. Also included in its 2013 order, the MoPSC authorized Ameren Missouri to employ a tracker allowing Ameren Missouri to record its costs incurred under its solar rebate program as a regulatory asset. Ameren Missouri will recover the costs of these rebates, and the carrying cost of the regulatory asset, which is estimated to be $9 million, over a three-year period beginning with the effective date of its next electric rate case. Energy Efficiency Ameren’s rate-regulated utilities have implemented energy efficiency programs to educate and help their customers become more efficient users of energy. The MEEIA established a regulatory framework that, among other things, allows electric utilities to recover costs related to MoPSC-approved 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 standards. The MoPSC’s December 2012 electric rate order approved Ameren Missouri’s implementation of MEEIA megawatthour savings targets, energy efficiency programs, and associated cost recovery mechanisms and incentive awards. In 2013, Ameren Missouri invested $35 million for energy efficiency programs. Ameren Missouri expects to invest $48 million in 2014 and $64 million in 2015 for these programs. A MEEIA rider allows Ameren Missouri to collect from or refund to customers through 2015 any annual difference in the actual amounts incurred and the projected amounts collected from customers for the MEEIA program costs and its projected lost revenues. Additionally, MEEIA provides an incentive award that would allow Ameren Missouri to earn additional revenues by achieving certain energy efficiency goals, including approximately $19 million if 100% of its energy efficiency goals are achieved during the three-year period, with the potential to earn more if Ameren Missouri’s energy savings exceed those goals. Ameren Missouri must achieve at least 70% of its energy efficiency goals before it earns any incentive award. The recovery of the incentive award from customers, if the energy efficiency goals are achieved, is expected in 2017 through the above-mentioned rider. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information. Illinois has enacted a law requiring Ameren Illinois to offer energy efficiency programs. The law also allows recovery mechanisms of the programs’ costs. The ICC has issued orders approving Ameren Illinois’ electric and natural gas energy efficiency plans as well as cost recovery mechanisms by which program costs can be recovered from customers. In addition, between 2012 and 2021, Ameren Illinois is required, pursuant to the IEIMA, to invest $625 million in capital projects incremental to Ameren Illinois’ average electric delivery service capital projects for calendar years 2008 through 2010 to modernize its distribution system. As part of these upgrades, Ameren Illinois expects to invest $360 million for smart grid infrastructure, including smart meters, which enables customers to improve efficiency. Ameren Illinois will begin the installation of smart meters during 2014. NATURAL GAS SUPPLY FOR DISTRIBUTION Ameren Missouri and Ameren Illinois are responsible for the purchase and delivery of natural gas to their utility customers. Ameren Missouri and Ameren Illinois each develop and manage a portfolio of natural gas supply resources. These include firm gas supply under term agreements with producers, interstate and intrastate firm transportation capacity, firm 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, financial instruments, including those entered into in the NYMEX futures market and in the OTC financial markets, are used to hedge the price paid for natural gas. See Part II, Item 7A – Quantitative and Qualitative Disclosures About Market Risk of this report for additional information about natural gas supply contracts. Natural gas purchase costs are passed on to customers of Ameren Missouri and Ameren Illinois under PGA clauses, subject to prudency reviews by the MoPSC and the ICC. As of December 31, 2013, Ameren Missouri had price-hedged 84%, and Ameren Illinois had price-hedged 77%, of its expected 2014 natural gas supply requirements. For additional information on our fuel and purchased power supply, see Results of Operations, Liquidity and Capital Resources and Effects of Inflation and Changing Prices in Management’s Discussion and Analysis of 13 Financial Condition and Results of Operations under Part II, Item 7, of this report. Also see Quantitative and Qualitative Disclosures About Market Risk under Part II, Item 7A, of this report, Note 1 – Summary of Significant Accounting Policies, Note 7 – Derivative Financial Instruments, Note 10 – Callaway Energy Center, Note 14 – Related Party Transactions, and Note 15 – Commitments and Contingencies 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: ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ political and regulatory resistance to higher rates; the potential for changes in laws, regulations, and policies at the state and federal level; cybersecurity risk, including loss of operational control of energy centers and electric and natural gas transmission and distribution systems and/or loss of data, such as utility customer data, account information, and intellectual property through insider or outsider actions; the potential for more intense competition in generation, supply and distribution, including new technologies; pressure on customer growth and usage in light of economic conditions and energy efficiency 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; pressure to reduce the allowed return on common equity on FERC-regulated electric transmission assets; the availability of fuel and increases or decreases in fuel prices; the availability of qualified labor and material, and rising costs; regulatory lag; OPERATING STATISTICS ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ the influence of macroeconomic factors, such as yields on United States treasury securities, on allowed rates of return on equity provided by regulators; decreased or negative free cash flows due to rising infrastructure investments and regulatory frameworks; public concern about the siting of new facilities; continually developing and complex environmental laws, regulations and requirements, including air and water quality standards, mercury emissions standards, and likely greenhouse gas limitations and CCR management requirements; public concerns about the potential impacts to the environment from the combustion of fossil fuels; aging infrastructure and the need to construct new power generation, transmission and distribution facilities, which have long time frames for completion, while at the same time, having little long-term visibility on power and commodity prices and regulatory requirements; legislation or proposals for programs to encourage or mandate energy efficiency and renewable sources of power, such as solar, and the macroeconomic debate of who should pay for those programs; public concerns about nuclear generation and decommissioning and the disposal of nuclear waste; and consolidation of electric and natural gas companies. We are monitoring 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, and 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 and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. 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, 2013 2012 2011 Electric Sales – kilowatthours (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Native load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system and wholesale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13,562 14,634 8,709 125 37,030 6,128 43,158 13,385 14,575 8,660 126 36,746 7,293 44,039 13,867 14,743 8,691 127 37,428 10,715 48,143 14 Electric Operating Statistics – Year Ended December 31, 2013 2012 2011 Ameren Illinois: Residential Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Native load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5,474 6,310 2,606 9,541 1,667 10,861 522 36,981 Eliminate affiliate sales . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (82) 9,507 2,103 2,985 9,175 1,595 11,753 523 37,641 - Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80,057 81,680 Electric Operating Revenues (in millions): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Native load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system and wholesale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Residential Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial Power supply and delivery service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Delivery service only . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Native load subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Eliminate affiliate revenues and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Electric Generation – Ameren Missouri – megawatthours (in millions) . . . . . . . . . . . . . . . . . . . . . Price per ton of delivered coal (average) – Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren source of energy supply: Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Methane gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased – Wind . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased – Other $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,428 1,216 491 61 3,196 183 3,379 501 282 215 184 70 44 165 1,461 (8) 4,832 43.2 36.19 70.2% 10.5 1.6 1.1 0.1 0.4 16.1 $ $ $ $ $ $ $ 1,297 1,088 435 104 2,924 208 3,132 961 90 254 177 57 46 154 1,739 (14) 4,857 44.7 34.21 65.1% 12.4 1.1 2.7 - 0.4 18.3 11,771 77 3,662 8,561 1,502 11,360 529 37,462 (17) 85,588 1,272 1,084 438 76 2,870 352 3,222 1,194 3 350 157 65 43 128 1,940 (15) 5,147 48.8 30.57 66.5% 9.4 1.3 1.1 - 0.3 21.4 100.0% 100.0% 100.0% 15 Gas Operating Statistics – Year Ended December 31, 2013 2012 2011 Natural Gas Sales (millions of dekatherms): Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport and other Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural Gas Operating Revenues (in millions) Ameren Missouri: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport and other Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transport and other Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Eliminate affiliate revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ 8 4 1 6 19 62 21 6 87 176 195 102 42 8 9 161 611 185 26 25 847 (2) 1,006 $ $ $ $ $ 6 3 1 6 16 49 17 5 86 157 173 85 36 8 10 139 547 172 24 43 786 (1) 924 $ $ $ $ $ 7 3 1 5 16 56 21 5 80 162 178 96 42 9 9 156 588 195 30 33 846 (1) 1,001 AVAILABLE INFORMATION The Ameren Companies make available free of charge through Ameren’s website (www.ameren.com) their annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, eXtensible Business Reporting Language (XBRL) documents, and any amendments to those reports filed with or furnished to 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 an Internet website maintained by the SEC (www.sec.gov). Ameren also uses its website as a channel of distribution of material information relating to the Ameren Companies. Financial and other material information regarding the Ameren Companies 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 oversight and environmental committee; the corporate governance guidelines; a policy regarding communications to the board of directors; a policy and procedures with respect to related-person transactions; a code of ethics for principal executive and senior financial officers; a code of business conduct applicable to all directors, officers and employees; 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. See Forward-Looking Statements above and Outlook in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report. The Ameren Companies are subject to extensive regulation of their businesses, which could adversely affect their results of operations, financial position, and liquidity. The Ameren Companies are subject to, or affected by, extensive federal, state, and local regulation. This extensive regulatory framework, some but not all of which is more specifically identified in the following risk factors, regulates, 16 among other matters, the electric and natural gas utility industries; rate and cost structure of utilities; operation of nuclear energy centers; construction and operation of generation, transmission, and distribution facilities; acquisition, disposal, depreciation and amortization of assets and facilities; transmission reliability; and present or prospective wholesale and retail competition. The Ameren Companies must address in their planning and management of operations the effects of existing and proposed laws and regulations and potential changes in the regulatory framework, including initiatives by federal and state legislatures, RTOs, utility regulators, and taxing authorities. Significant changes in the nature of the regulation of the Ameren Companies’ businesses could require changes to their business planning and management of their businesses and could adversely affect their results of operations, financial position, and liquidity. Failure of the Ameren Companies to obtain adequate rates or regulatory approvals in a timely manner, failure to obtain necessary licenses or permits from regulatory authorities, new or modified laws, regulations, standards, interpretations, or other legal requirements, or increased compliance costs could adversely impact the Ameren Companies’ results of operations, financial position, and liquidity. The electric and natural gas rates that Ameren Missouri and Ameren Illinois are allowed to charge are determined through regulatory proceedings, which are subject to intervention and appeal, and are subject to legislative actions, which are largely outside of their control. Any events that prevent Ameren Missouri or Ameren Illinois from recovering their respective costs or from earning adequate returns on their investments could adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. The rates that Ameren Missouri and Ameren Illinois 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 industries are extensively regulated. The utility rates charged to Ameren Missouri and Ameren Illinois customers are determined, in large part, by governmental entities, including the MoPSC, the ICC, and 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, economic conditions, public policy, and social and political views. Decisions made by these governmental entities regarding rates are largely outside of Ameren Missouri’s and Ameren Illinois’ control. Ameren’s utility operations are exposed to regulatory lag to varying degrees by jurisdiction, which, if unmitigated, has a material adverse effect on our results of operations, financial position, and liquidity. Rate orders are also subject to appeal, which creates additional uncertainty as to the rates Ameren Missouri and Ameren Illinois will ultimately be allowed to charge for their services. Ameren Missouri 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. Rates established in those proceedings for Ameren Missouri are primarily based on historical costs and revenues. Natural gas rates established in those proceedings for Ameren Illinois may be based on historical or estimated future costs and revenues. Thus, the rates a utility is allowed to charge may not match its costs at any given time. Rates include an allowed rate of return on investments determined by the regulators. Although rate regulation is premised on providing an opportunity to earn a reasonable rate of return on invested capital, there can be no assurance that the applicable regulatory commission will determine that all the costs of Ameren Missouri and Ameren Illinois have been prudently incurred or that the regulatory process will result in rates that will produce full recovery of such costs or an adequate return on those investments. In years when capital investments and operations costs rise while customer usage declines, Ameren Missouri and Ameren Illinois may not be able to earn the allowed return established by their state commissions. This could result in the deferral or elimination of planned capital investments, which would reduce the rate base investments from which the utility operations earn a rate of return. Additionally, increasing rates for our customers could result in additional regulatory and legislative actions, as well as competitive and political pressures, which could adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. Through its participation in the performance-based formula ratemaking process established pursuant to the IEIMA, Ameren Illinois’ return on equity for its electric distribution business will be directly correlated to yields on United States treasury bonds. Additionally, Ameren Illinois will be subject to an annual ICC prudence review, and Ameren Illinois will be required to achieve performance objectives, increase capital spending levels, and meet job creation targets. Failure to meet these requirements could adversely affect Ameren Illinois’ results of operations, financial position, and liquidity. Ameren Illinois is participating in the performance- based formula ratemaking process established pursuant to the IEIMA for its electric distribution business. The ICC annually reviews Ameren Illinois’ performance-based rate filings under the IEIMA for reasonableness and prudency. If the ICC were to conclude that Ameren Illinois’ incurred costs were not prudently incurred, the ICC would disallow recovery of such costs. The return on equity component of the formula rate is equal to the average for the calendar year of the monthly yields of 30-year United States treasury bonds plus 580 basis points. Therefore, Ameren Illinois’ annual return on equity under the formula ratemaking process for its electric distribution business is directly correlated to yields on such bonds, which are outside of Ameren Illinois’ control. 17 Ameren Illinois is also subject to performance standards. Failure to achieve the standards would result in a reduction in the company’s allowed return on equity calculated under the formula. The IEIMA provides for return on equity penalties totaling 30 basis points in 2013 through 2015, 34 basis points in 2016 through 2018, and 38 basis points in 2019 through 2022 if the performance standards are not met. Between 2012 and 2021, Ameren Illinois is required to invest $625 million in capital projects incremental to Ameren Illinois’ average electric delivery capital projects for calendar years 2008 through 2010 to modernize its distribution system. Ameren Illinois is subject to monetary penalties if 450 additional jobs are not created in Illinois during the peak program year. The formula ratemaking process would terminate if the average residential rate increases by more than 2.5% annually from June 2011 through May 2014. The average residential rate includes generation service, which is outside of Ameren Illinois’ control, as Ameren Illinois is required to purchase all of its power through procurement processes administered by the IPA. If the performance-based formula rate process is terminated, Ameren Illinois would be required to establish future rates through a traditional rate proceeding with the ICC, which might not result in rates that produce a full or timely recovery of costs or an adequate return on investments. Unless it is extended, the IEIMA formula ratemaking process expires in 2017. Customers’, legislators’ and regulators’ opinions of us are affected by our ability to provide reliable utility service to our customers. Failure to provide such reliable utility service could result in customers and regulators having a negative opinion of us, which, in turn, could adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. Ameren’s utility subsidiaries provide utility service to 2.4 million electric customers and 0.9 million natural gas customers. Service interruptions due to failures of equipment or facilities as a result of severe or destructive weather or other causes, and the ability of Ameren Missouri and Ameren Illinois to promptly respond to such failures, can affect customer satisfaction. In addition to system reliability issues, the success of modernization efforts, such as those planned for Ameren Illinois’ electric and natural gas delivery systems, and other public actions of the Ameren Companies can affect customer satisfaction. Rate increases and volatility of rates can also affect customer satisfaction. If customers, legislators or regulators have a negative opinion of us and our utility services, this could result in increased regulatory oversight of the Ameren Companies and could impact the returns on common equity we are allowed to earn. Additionally, negative opinions of the Ameren Companies could make it more difficult for our utilities to achieve favorable legislative or regulatory outcomes. Any of these consequences could adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. Energy conservation, energy efficiency, distributed generation, and other factors that reduce energy demand could adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. Regulatory and legislative bodies have proposed or introduced requirements and incentives to reduce energy consumption. Conservation and energy efficiency programs are designed to reduce energy demand. Unless there is a regulatory solution ensuring recovery, declining usage will result in an under-recovery of fixed costs at our rate- regulated businesses. Ameren Missouri, even with the implementation of energy efficiency programs under the MEEIA, is exposed to declining usage losses from energy efficiency efforts not related to its specific programs as well as distributed generation sources such as solar panels. Macroeconomic factors resulting in low economic growth or contraction within the Ameren Companies’ service territories could also reduce energy demand. We are subject to various environmental laws and regulations. Significant capital expenditures are required to achieve and maintain compliance with their standards. Failure to meet these standards could result in closure of facilities, alterations to the manner in which these facilities operate, increased operating costs, adverse impacts to our results of operations, financial position, and liquidity, or exposure to fines and liabilities. We are subject to various environmental laws and regulations enforced by federal, state, and local authorities. From the beginning phases of siting and development to the operation of existing or new electric generating, transmission and distribution facilities and natural gas storage, transmission and distribution facilities, our activities involve compliance with diverse environmental laws and regulations. These laws and regulations address emissions; water discharges and usage; impacts to air, land, and water; noise; protected natural and cultural resources (such as wetlands, endangered species, and other protected wildlife, and archaeological and historical resources); and chemical and waste handling. Complex and lengthy processes are required to obtain approvals, permits, or licenses for new, existing, or modified facilities. Additionally, the use and handling of various chemicals or hazardous materials (including wastes) requires release prevention plans and emergency response procedures. We are also subject to liability under environmental laws that address the remediation of environmental contamination of property now or formerly owned by us or by our predecessors, as well as property contaminated by hazardous substances that we generated. Such sites include MGP sites and third-party sites, such as landfills. Additionally, private individuals may seek to enforce environmental laws and regulations against us and could allege injury from exposure to hazardous materials or seek to compel remediation of environmental contamination or recover damages resulting from that contamination. The EPA is developing environmental regulations that will have a significant impact on the electric utility industry 18 over time. These regulations could be particularly burdensome for certain companies, including Ameren Missouri, that operate coal-fired energy centers. These new regulations may be litigated, so the timing of their ultimate implementation and our required compliance is uncertain. Ameren is also subject to risks in connection with changing or conflicting interpretations of existing laws and regulations. The EPA is engaged in an enforcement initiative to determine whether coal-fired energy centers failed to comply with the requirements of the NSR and NSPS provisions under the Clean Air Act when the energy centers implemented modifications. In January 2011, the 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. The EPA’s complaint, as amended in October 2013, alleges that in performing projects at its Rush Island coal-fired energy center in 2007 and 2010, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. In January 2012, the United States District Court granted, in part, Ameren Missouri’s motion to dismiss various aspects of the EPA’s penalty claims. The EPA’s claims for unspecified injunctive relief remain. Trial in this matter is currently scheduled to begin in January 2015. An outcome in this matter adverse to Ameren Missouri could require substantial capital expenditures and the payment of substantial penalties, neither of which can be determined at this time. Such expenditures could affect unit retirement and replacement decisions. Ameren and Ameren Missouri have incurred and expect to incur significant costs related to environmental compliance and site remediation. New environmental regulations, revised environmental regulations, enforcement initiatives, or legislation could result in a significant increase in capital expenditures and operating costs, decreased revenues, increased financing requirements, penalties, or fines, or closure of facilities for Ameren and Ameren Missouri. Actions required to ensure that our facilities and operations are in compliance with environmental laws and regulations could be prohibitively expensive if the costs are not recovered through rates. As a result, environmental laws could also require us to close or to significantly alter the operation of our energy centers, which could have an adverse effect on our results of operations, financial position, and liquidity. Costs incurred by Ameren Missouri to ensure that its facilities are in compliance with environmental laws and regulations would be eligible for recovery in rates over time, subject to MoPSC approval in a rate proceeding. We are unable to predict the ultimate impact of these matters on our results of operations, financial position, and liquidity. Future limits on greenhouse gas emissions may require Ameren Missouri to incur significant increases in capital expenditures and operating costs, which, if excessive and not recoverable through rate proceedings, could result in the closures of coal-fired energy centers, impairment of assets, or otherwise adversely affect our results of operations, financial position, and liquidity. State and federal authorities, including the United States Congress, have considered initiatives to limit greenhouse gas emissions. Potential impacts from any such legislation or regulation could vary, depending upon proposed CO2 emission limits, the timing of implementation of those limits, the method of distributing any allowances, the degree to which offsets are allowed and available, and provisions for cost-containment measures, such as a “safety valve” provision that provides a maximum price for emission allowances. Emissions of greenhouse gases vary among our energy centers, but coal-fired energy centers are significant sources of CO2. The enactment of a law that restricts emissions of CO2 or requires energy centers to purchase allowances for CO2 emission could result in a significant increase in rates for electricity, and accordingly, in household costs. The burden could fall particularly hard on electricity consumers and the economy in the Midwest because of the region’s reliance on electricity generated by coal-fired energy centers. In June 2013, the Obama administration announced that it had directed the EPA to set CO2 emissions standards for both new and existing power plants. The EPA published proposed regulations in January 2014 that would set revised CO2 emissions standards for new electricity generating units. The proposed standards would establish separate emissions limits for new natural gas-fired plants and new coal-fired plants. In addition, the Obama administration directed the EPA to propose a CO2 emissions standard for existing power plants by June 2014 and to finalize such standards by June 2015. Future federal or state legislation or regulations that mandate limits on the emission of greenhouse gases would likely result in significant increases in our capital expenditures and operating costs, which, in turn, could lead to increased liquidity needs and higher financing costs. Moreover, if Ameren Missouri requests recovery of these costs through rates, its regulators could deny some or all of these costs, or prevent timely recovery of them. Excessive costs to comply with future legislation or regulations that are not recoverable through rate proceedings might force Ameren Missouri to close coal-fired energy centers earlier than planned, which would lead to impairment of assets and reduced revenues. As a result, greenhouse gas emission limits could have a material adverse impact on Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. 19 The construction of, and capital improvements to, the Ameren Companies’ electric and natural gas utility infrastructure involve substantial risks. These risks include escalating costs, unsatisfactory performance by the projects when completed, the inability to complete projects as scheduled, cost disallowances by regulators, and the inability to earn an adequate return on invested capital, any of which could result in higher costs and the closure of facilities. The Ameren Companies expect to incur significant capital expenditures to comply with existing and known environmental regulations and to make investments in their electric and natural gas utility infrastructure. Ameren estimates it will incur up to $8.7 billion (Ameren Missouri – up to $3.5 billion; Ameren Illinois – up to $3.7 billion; other – up to $1.5 billion) of capital expenditures during the period 2014 through 2018. These estimates include allowance for funds used during construction. Investments in Ameren’s rate-regulated operations are expected to be recoverable from ratepayers, but are subject to prudency reviews and regulatory lag. The ability of the Ameren Companies to complete construction projects successfully within projected estimates is contingent upon many variables and subject to substantial risks. These variables include, but are not limited to, project management expertise and escalating costs for materials, labor, and environmental compliance. Delays in obtaining permits, shortages in materials and qualified labor, suppliers and contractors who do not perform as required under their contracts, changes in the scope and timing of projects, the inability to raise capital on reasonable terms, or other events beyond our control that could occur may materially affect the schedule, cost, and performance of these projects. With respect to capital expenditures for pollution control equipment, there is a risk that energy centers will not be permitted to continue to operate if pollution control equipment is not installed by prescribed deadlines or does not perform as expected. Should any such pollution control equipment not be installed on time or perform as expected, the Ameren Companies could be subject to additional costs and to the loss of their investment in the project or facility. All of these risks may adversely affect the Ameren Companies’ results of operations, financial position, and liquidity. As of December 31, 2013, Ameren Missouri had capitalized $69 million of costs incurred to license additional nuclear generation at its Callaway energy site. If efforts are abandoned or management concludes it is probable the costs incurred will be disallowed in rates, a charge to earnings would be recognized in the period in which that determination was made. We may not be able to execute our electric transmission investment plans and realize the expected return on those investments. Ameren, through ATXI and Ameren Illinois, is allocating significant additional capital resources to electric transmission investments. This allocation of capital resources is based on FERC’s regulatory framework and a rate of return on common equity that is currently higher than allowed by our state commissions. However, the FERC regulatory framework and rate of return is subject to change. The regulatory framework may not be as favorable, or the rate of return may be lower, in the future. Currently, the FERC-allowed return on common equity for MISO transmission owners is 12.38%. In 2013, a FERC administrative law judge issued an initial decision stating that the current 11.14% allowed rate of return for New England transmission owners was unjust and unreasonable. FERC has not issued its final order in this case, and it is under no deadline to do so. In November 2013, a complaint case was filed with FERC seeking a reduction in the allowed return on common equity, as well as a limit on the common equity ratio, under the MISO tariff. This complaint case could result in a reduction to Ameren Illinois’ and ATXI’s allowed return on common equity. That reduction could also result in a refund for transmission service revenues earned after the filing of the complaint case in November 2013. As in the New England transmission owners’ case, discussed above, FERC has not issued an order in this case, and it is under no deadline to do so. A significant portion of our planned electric transmission investments consists of three separate projects to be constructed by ATXI, which have been approved by MISO as multi-value projects. The largest of the three projects is the Illinois Rivers project. The total investment in these three projects is expected to be $1.4 billion. The last of these projects is expected to be completed in 2019. A failure by Ameren to complete all of these three projects on time and within projected cost estimates could adversely affect our results of operations, financial position, and liquidity. FERC has issued multiple orders, which are subject to ongoing litigation, eliminating the right of first refusal for electric utilities to construct certain new transmission projects within their service territory. If these orders are upheld by the courts, Ameren might need to compete to build certain future electric transmission projects in its subsidiaries’ service territories. Such competition could prevent Ameren from investing in future electric transmission projects to the extent desired. Our electric generation, transmission and distribution facilities are subject to operational risks that could adversely affect our results of operations, financial position, and liquidity. The Ameren Companies’ 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; older generating equipment that may require significant expenditures to operate at peak efficiency; 20 ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ disruptions in the delivery of fuel or lack of adequate inventories, including ultra-low-sulfur coal used for Ameren Missouri’s compliance with environmental regulations; lack of water required for cooling plant operations; labor disputes; inability to comply with regulatory or permit requirements, including those relating to environmental laws; disruptions in the delivery of electricity that impact our customers; handling and storage of fossil-fuel combustion byproducts, such as CCR; unusual or adverse weather conditions, including severe storms, droughts, floods, tornadoes, solar flares, and electromagnetic pulses; a workplace accident that might result in injury or loss of life, extensive property damage, or environmental damage; cybersecurity risk, including loss of operational control of our energy centers and our electric transmission and distribution systems and/or loss of data, such as utility customer data, account information, and intellectual property through insider or outsider actions; catastrophic events such as fires, explosions, pandemic health events, or other similar occurrences; limitations on amounts of insurance available to cover losses that might arise in connection with operating our electric generation, transmission, and distribution facilities; and other unanticipated operations and maintenance expenses and liabilities. 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 the risks of nuclear generation, which include the following: ‰ potential harmful effects on the environment and human health resulting from the operation of nuclear facilities and the storage, handling, and disposal of radioactive materials; the lack of a permanent waste storage site; limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with the Callaway energy center or other United States nuclear operations; uncertainties with respect to contingencies and retrospective premium assessments relating to claims at the Callaway energy center or any other United States nuclear energy center; public and governmental concerns about the adequacy of security at nuclear energy centers; uncertainties with respect to the technological and financial aspects of decommissioning nuclear energy centers at the end of their licensed lives; limited availability of fuel supply; and costly and extended outages for scheduled or unscheduled maintenance and refueling. ‰ ‰ ‰ ‰ ‰ ‰ ‰ The NRC has broad authority under federal law to impose licensing and safety requirements for nuclear energy centers. 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 nuclear energy centers such as Ameren Missouri’s. In addition, if a serious nuclear incident were to occur, it could have a material but indeterminable adverse effect on Ameren Missouri’s results of operations, financial condition, and liquidity. A major incident at a nuclear energy center anywhere in the world could cause the NRC to limit or prohibit the operation or relicensing of any domestic nuclear unit. An incident at a nuclear energy center anywhere in the world also could cause the NRC to impose additional conditions or requirements on the industry, which could increase costs and result in additional capital expenditures. For example, the earthquake in 2011 that affected nuclear energy centers in Japan has resulted in regulatory changes in the United States, and may result in future regulatory changes that may impose additional costs on all nuclear energy centers in the United States. Specific to seismic risk, the NRC may require Callaway to further evaluate the impact of an earthquake on its operations, which could lead to the installation of additional capital equipment to comply with revised NRC standards. Our natural gas distribution and storage activities involve numerous risks that may result in accidents and other operating risks and costs that could adversely affect our results of operations, financial position, and liquidity. Inherent in our natural gas distribution and storage activities are a variety of hazards and operating risks, such as leaks, accidental explosions, mechanical problems and cybersecurity risks, which could cause substantial financial losses. In addition, these risks could result in serious injury, loss of human life, significant damage to property, environmental pollution, and impairment of our operations, which in turn could lead to substantial losses for us. In accordance with customary industry practice, we maintain insurance against some, but not all, of these risks and losses. The location of distribution lines 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. The occurrence of any of these events not fully covered by insurance could materially adversely affect our results of operations, financial position, and liquidity. We are subject to federal regulatory compliance and proceedings, which increase our risk of regulatory penalties and other sanctions. The Energy Policy Act of 2005 increased FERC’s civil penalty authority for violation of FERC statutes, rules, and orders, including with respect to mandatory NERC reliability standards. FERC can impose penalties of $1 million per violation per day. Under the Energy Policy Act of 2005, the Ameren Companies, as owners and operators of bulk power 21 transmission systems and/or electric energy centers, are subject to mandatory NERC reliability standards, including cybersecurity standards. Compliance with these mandatory reliability standards may subject the Ameren Companies to higher operating costs and may result in increased capital expenditures. If the Ameren Companies were found not to be in compliance with these mandatory reliability standards or FERC statutes, rules and orders, the Ameren Companies could incur substantial monetary penalties and other sanctions, which could adversely affect our results of operations, financial position, and liquidity. FERC also conducts audits and reviews of Ameren Missouri’s, Ameren Illinois’, and ATXI’s accounting records to assess the accuracy of its formula rate-making process and has the ability to require retroactive refunds to customers for previously billed amounts, with interest. Even though agreements were reached with the state of Missouri and FERC, the breach of the upper reservoir of Ameren Missouri’s Taum Sauk pumped-storage hydroelectric energy center could continue to have a material adverse effect on Ameren’s and Ameren Missouri’s results of operations, liquidity, and financial condition. In December 2005, there was a breach of the upper reservoir at Ameren Missouri’s Taum Sauk pumped-storage hydroelectric energy center. This resulted in significant flooding in the local area, which damaged a state park. Ameren Missouri settled with the state of Missouri and FERC all issues associated with the December 2005 Taum Sauk incident. Ameren Missouri had liability insurance coverage for the Taum Sauk incident, subject to certain limits and deductibles. Ameren Missouri filed separate lawsuits against two different liability insurance providers claiming that the insurance companies breached their duty to indemnify Ameren Missouri for the losses experienced from the incident. Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity could be adversely affected if Ameren Missouri’s remaining liability insurance claims of $68 million as of December 31, 2013, are not paid by insurers. Our businesses are dependent on our ability to access the capital markets successfully. We may not have access to sufficient capital in the amounts and at the times needed. We rely on short-term and long-term debt as significant sources of liquidity and funding for capital requirements not satisfied by our operating cash flow as well as to refinance long-term debt. The inability to raise debt or equity capital on reasonable terms, or at all, could negatively affect our ability to maintain and to expand our businesses. Events beyond our control, such as a recession or extreme volatility in the debt, equity, or credit markets, may 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 the Ameren Companies’ credit ratings may reduce access to capital and trigger additional collateral postings and prepayments. Such changes may also increase the cost of borrowing and fuel, power and natural gas supply, among other things, which could have a material adverse effect on our results of operations, financial position, and liquidity. Certain of the Ameren’s subsidiaries, such as ATXI, rely on Ameren for access to capital. Circumstances that limit Ameren’s access to capital could impair its ability to provide those subsidiaries with needed capital. 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 the common stock of its subsidiaries. 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 also dependent upon the earnings of operating subsidiaries and the distribution of those earnings and other payments, including payments of principal and interest under intercompany indebtedness. The payment of dividends to Ameren by its subsidiaries in turn depends on their results of operations and cash flows and other items affecting retained earnings. 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 intercompany borrowing arrangements and cash payments and receipts under the tax allocation agreement) to Ameren. Certain of the Ameren Companies’ financing agreements and articles of incorporation, in addition to certain statutory and regulatory requirements, may impose restrictions on the ability of such Ameren Companies to transfer funds to Ameren in the form of cash dividends, loans, or advances. Dynegy’s or its subsidiaries’ failure to satisfy certain of their indemnity and other obligations to Ameren in connection with the divestiture of New AER to IPH could have a material adverse impact on Ameren’s results of operations, financial position or liquidity. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. The transaction agreement between Ameren and IPH requires Ameren, for up to 24 months after the closing of the divestiture of New AER, to maintain its financial obligations in existence as of the date of the closing under all credit support arrangements or obligations with respect to New AER and its subsidiaries. Ameren must also provide any additional credit support that may be contractually required pursuant to any of the contracts of New AER, and its subsidiaries as of the closing. IPH, New AER and its subsidiaries and Dynegy have agreed to indemnify Ameren for certain losses relating to this credit support. IPH’s indemnification obligations are secured by certain AERG and Genco assets. However, these indemnification obligations and security interests might not cover all losses incurred by Ameren in connection with this 22 credit support. In addition, Dynegy emerged from its Chapter 11 bankruptcy case on October 1, 2012, and, as of December 31, 2013, Dynegy’s credit ratings were sub- investment grade. IPH, New AER and its subsidiaries also do not have investment grade credit ratings. Dynegy, IPH, New AER, or their subsidiaries might not be able to pay their indemnity and other obligations under the transaction agreement, Marketing Company’s note to Ameren, or Dynegy’s limited guarantee to Ameren, which could have a material adverse impact on Ameren’s results of operations, financial position, and liquidity. As of December 31, 2013, the balance of the Marketing Company note to Ameren was $18 million. As of December 31, 2013, Ameren provided $190 million in guarantees and letters of credit totaling $11 million relating to its credit support of New AER. Government challenges to the tax positions taken by the Ameren Companies, as well as tax law changes and the inherent difficulty in quantifying potential tax effects of business decisions could adversely affect the Ameren Companies’ results of operations and cash flows. The Ameren Companies are required to make judgments in order to estimate their obligations to taxing authorities. These obligations can include income tax and taxes other than income tax, many of which involve complex matters that ultimately could be determined by the courts. These judgments include reserves for potential adverse outcomes for tax positions that may be challenged by tax authorities. The Ameren Companies also estimate their ability to use tax benefits, including those in the form of carryforwards and tax credits that are recorded as deferred tax assets on their balance sheets. A disallowance of these tax benefits could have a material adverse impact on our results of operation, financial position, and liquidity. The Ameren Companies’ operations are subject to acts of sabotage, war, 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 information systems may be targets of terrorist activities, including cyber attacks, which could disrupt our ability to produce or distribute some portion of our energy products. Any such disruption could result in a significant decrease in revenues or significant additional costs for repair, which could adversely affect our results of operations, financial position, and liquidity. A security breach of the Ameren Companies’ physical assets or information systems could affect the reliability of the transmission and distribution system, disrupt electric generation, and/or subject the Ameren Companies to financial harm associated with theft or inappropriate release of certain types of information, including sensitive customer and employee data. If a significant breach occurred, the reputation of the Ameren Companies could be adversely affected, customer confidence could be diminished, and/or the Ameren Companies could be subject to legal claims, any of which could result in a significant decrease in revenues or significant additional costs for rectifying the impacts of such a breach. The Ameren Companies’ use of smart meters throughout their service territories may increase the risk of damage from an intentional disruption of the system by third parties. In addition, new or updated security regulations could require changes in current measures taken by the Ameren Companies and could adversely affect their results of operations, cash flows, and financial position. Increasing costs associated with our defined benefit retirement and postretirement plans, health care plans, and other employee benefits could adversely affect our financial position and liquidity. We offer defined benefit retirement and postretirement plans that cover substantially all of our employees. Assumptions related to future costs, returns on investments, interest rates, and other actuarial matters have a significant impact on our customers’ rates and our plan funding requirements. Ameren expects to fund its pension plans at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering Ameren’s assumptions at December 31, 2013, its investment performance in 2013, and its pension funding policy, Ameren expects to make annual contributions of $20 million to $100 million in each of the next five years, with aggregate estimated contributions of $270 million. We expect Ameren Missouri’s and Ameren Illinois’ portion of the future funding requirements to be 52% and 47%, respectively. These amounts are estimates. They may change with 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 retirement 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. The increasing costs and funding requirements associated with our defined benefit retirement plans, health care plans, and other employee benefits could increase our financing needs and otherwise materially adversely affect our financial position and liquidity. Failure to retain and attract key officers and other skilled professional and technical employees could adversely affect our operations. Our businesses depend upon our ability to employ and retain key officers and other skilled professional and technical employees. A significant portion of our workforce is nearing retirement, including many employees with specialized skills such as maintaining and servicing our electric and natural gas infrastructure and operating our energy centers. ITEM 1B. UNRESOLVED STAFF COMMENTS None. 23 ITEM 2. PROPERTIES For information on our principal properties, see the energy center table 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, replacements or transfers. See also Note 5 – Long-term Debt and Equity Financings, and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. The following table shows what the capability of our Ameren Missouri energy centers is anticipated to be at the time of our expected 2014 peak summer electrical demand: Primary Fuel Source Energy Center Location Net Kilowatt Capability(a) Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total hydroelectric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Labadie Rush Island Sioux Meramec Callaway Osage Keokuk Franklin County, Missouri Jefferson County, Missouri St. Charles County, Missouri St. Louis County, Missouri Callaway County, Missouri Lakeside, Missouri Keokuk, Iowa Pumped-storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taum Sauk Reynolds County, Missouri Oil (CTs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total oil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas (CTs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Meramec Fairgrounds Mexico Moberly Moreau Howard Bend Audrain(b) Venice(c) Goose Creek Pinckneyville Raccoon Creek Kinmundy(c) Peno Creek(b)(c) Meramec(c) Kirksville St. Louis County, Missouri Jefferson City, Missouri Mexico, Missouri Moberly, Missouri Jefferson City, Missouri St. Louis County, Missouri Audrain County, Missouri Venice, Illinois Piatt County, Illinois Pinckneyville, Illinois Clay County, Illinois Kinmundy, Illinois Bowling Green, Missouri St. Louis County, Missouri Kirksville, Missouri Total natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Methane gas (CTs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Maryland Heights Maryland Heights, Missouri Total Ameren and Ameren Missouri . . . . . . . . . . . . . . . 2,374,000 1,182,000 972,000 831,000 5,359,000 1,193,000 240,000 140,000 380,000 440,000 54,000 54,000 53,000 53,000 53,000 39,000 306,000 600,000 487,000 432,000 316,000 300,000 206,000 188,000 44,000 13,000 2,586,000 8,000 10,272,000 (a) Net kilowatt capability is the generating capacity available for dispatch from the energy center into the electric transmission grid. (b) There are economic development lease arrangements applicable to these CTs. (c) These CTs have the capability to operate on either oil or natural gas (dual fuel). The following table presents electric and natural gas utility-related properties for Ameren Missouri and Ameren Illinois as of December 31, 2013: Circuit miles of electric transmission lines(a) . . . Circuit miles of electric distribution lines . . . . . . Circuit miles of electric distribution lines Ameren Missouri Ameren Illinois 2,956 33,076 4,548 46,011 underground . . . . . . . . . . . . . . . . . . . . . . . . . 23% 15% Our other properties include office buildings, warehouses, garages, and repair shops. 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: Miles of natural gas transmission and distribution mains . . . . . . . . . . . . . . . . . . . . . Underground gas storage fields . . . . . . . . . . . . . Total working capacity of underground gas 3,297 - 18,190 12 ‰ storage fields in billion cubic feet . . . . . . . . . - 24 (a) ATXI owns 29 miles of transmission lines not reflected in this table. A portion of Ameren Missouri’s Osage energy center reservoir, certain facilities at Ameren Missouri’s Sioux energy center, most of Ameren Missouri’s Peno Creek and Audrain CT energy centers, certain substations, and most transmission and distribution lines and natural gas mains are situated on lands occupied under 24 leases, easements, franchises, licenses, or permits. The United States or the state of Missouri may own or may have paramount rights 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 first 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, and leased the energy center back from the city through 2022. Under the terms of this capital lease, 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 lease, at which time the property and plant will become subject to the lien of any outstanding Ameren Missouri first mortgage bond indenture. Ameren Missouri operates a CT energy center located in Audrain County, Missouri. Ameren Missouri has rights and obligations as lessee of the CT energy center under a long-term lease with Audrain County. The lease will expire on December 1, 2023. Under the terms of this capital lease, 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 lease, at which time the property and plant will become subject to the lien of any outstanding Ameren Missouri first 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. Material legal and administrative proceedings, which are discussed in Note 2 – Rate and Regulatory Matters and Note 15 – Commitment and Contingencies under Part II, Item 8, of this report and are incorporated herein by reference, include the following: ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ Ameren Illinois’ appeal of the ICC’s December 2013 electric rate order; FERC litigation to determine wholesale distribution revenues for five of Ameren Illinois’ wholesale customers; Complaint cases filed by Noranda and 37 residential customers with the MoPSC in February 2014 requesting a reduction to Ameren Missouri’s electric rates, including a reduction to its allowed return on equity, and certain rate design changes; Entergy’s rehearing request of a FERC May 2012 order requiring Entergy to refund to Ameren Missouri additional charges Ameren Missouri paid under an expired power purchase agreement; Ameren Illinois’ request for rehearing of FERC’s July 2012 and June 2013 orders regarding the inclusion of acquisition premiums in Ameren Illinois’ electric transmission rates; the EPA’s Clean Air Act-related litigation filed against Ameren Missouri; remediation matters associated with former MGP and waste disposal sites of the Ameren Companies; litigation associated with the breach of the upper reservoir at Ameren Missouri’s Taum Sauk pumped- storage hydroelectric energy center; Ameren Illinois’ receipt of tax liability notices relating to prior-period electric and natural gas municipal taxes; and asbestos-related litigation associated with Ameren, Ameren Missouri, and Ameren Illinois. 25 ITEM 4. MINE SAFETY DISCLOSURES Not applicable. EXECUTIVE OFFICERS OF THE REGISTRANTS (ITEM 401(b) OF REGULATION S-K): The executive officers of the Ameren Companies, including major subsidiaries, are listed below, along with their ages as of December 31, 2013, all positions and offices held with the Ameren Companies as of February 14, 2014, tenure as officer, and business background for at least the last five years. Some executive officers hold multiple positions within the Ameren Companies; their titles are given in the description of their business experience. References to “Ameren Illinois companies” below refers to CIPS, CILCO and IP collectively prior to the Ameren Illinois Merger and to Ameren Illinois following the Ameren Illinois Merger. AMEREN CORPORATION: Age Positions and Offices Held 66 Name Thomas R. Voss Voss joined Ameren Missouri in 1969. In 2007, Voss was elected chairman, president and chief executive officer of Ameren Missouri. In 2009, Voss was elected president and chief executive officer of Ameren; at that time, he relinquished his other positions. In 2010, the Ameren board of directors elected Voss to the additional position of chairman of the board. He has been a member of the Ameren board since 2009. Voss relinquished his position as president of Ameren, effective February 14, 2014, and will relinquish his position as chief executive officer of Ameren, effective April 24, 2014, and will retire as chairman and member of the Ameren board, effective July 1, 2014. Chairman and Chief Executive Officer, and Director 52 Warner L. Baxter Baxter joined Ameren Missouri in 1995. Baxter was elected to the positions of executive vice president and chief financial officer of Ameren, Ameren Missouri, CIPS, CILCO and Ameren Services in 2003 and of IP in 2004. He was elected chairman, president, chief executive officer and chief financial officer of Ameren Services in 2007. In 2009, Baxter was elected chairman, president and chief executive officer of Ameren Missouri; at that time, he relinquished his other positions. Baxter became president of Ameren and a member of the Ameren board, effective February 14, 2014, and will succeed Voss as chief executive officer of Ameren, effective April 24, 2014. The Ameren board expects that Baxter will succeed Voss as chairman of the board. President and Director Martin J. Lyons, Jr. Lyons joined Ameren in 2001. In 2008, Lyons was elected senior vice president and principal accounting officer of the Ameren Companies. In 2009, Lyons was also elected chief financial officer of the Ameren Companies. In 2013, Lyons was elected executive vice president and chief financial officer of the Ameren Companies, and relinquished his duties as principal accounting officer. Executive Vice President and Chief Financial Officer 47 Gregory L. Nelson Nelson joined Ameren Missouri in 1995. Nelson was elected vice president and tax counsel of Ameren Services in 1999 and vice president of Ameren Missouri, CIPS, and CILCO in 2003 and of IP in 2004. In 2010, Nelson was elected vice president, tax and deputy general counsel of Ameren Services. He remained vice president of Ameren Missouri and the Ameren Illinois companies. In 2011, Nelson was elected to the positions of senior vice president, general counsel and secretary of the Ameren Companies. Senior Vice President, General Counsel and Secretary 56 Bruce A. Steinke Steinke joined Ameren Services in 2002. In 2008, he was elected vice president and controller of Ameren, the Ameren Illinois companies and Ameren Services. In 2009, Steinke relinquished his positions at the Ameren Illinois companies. In 2013, Steinke was elected senior vice president, finance and chief accounting officer of the Ameren Companies. Senior Vice President, Finance and Chief Accounting Officer 52 SUBSIDIARIES: Name Maureen A. Borkowski Borkowski joined Ameren Missouri in 1981. She left the company in 2000 before rejoining Ameren in 2005 as vice president, transmission, of Ameren Services. In 2011, Borkowski was elected chairman, president and chief executive officer of ATXI. In 2011, she was also elected senior vice president, transmission, of Ameren Services. Age Positions and Offices Held 56 Chairman, President and Chief Executive Officer (ATXI) Daniel F. Cole Cole joined Ameren Missouri in 1976. He was elected senior vice president of Ameren Missouri and Ameren Services in 1999 and of CIPS in 2001. He was elected senior vice president of CILCO in 2003 and of IP in 2004. In 2009, Cole was elected chairman, president and chief executive officer of Ameren Services and remained senior vice president of Ameren Missouri and the Ameren Illinois companies. Chairman, President and Chief Executive Officer (Ameren Services) 60 26 Name Fadi M. Diya Diya joined Ameren Missouri in 2005. In 2008, Diya was elected vice president of nuclear operations at Ameren Missouri. Effective January 16, 2014, Diya was elected senior vice president and chief nuclear officer of Ameren Missouri. Age Positions and Offices Held 51 Senior Vice President and Chief Nuclear Officer (Ameren Missouri) Richard J. Mark Mark joined Ameren Services in 2002. He was elected senior vice president, customer operations of Ameren Missouri in 2005. In 2012, Mark relinquished his position at Ameren Missouri and was elected chairman, president and chief executive officer of Ameren Illinois. Chairman, President and Chief Executive Officer (Ameren Illinois) 58 Michael L. Moehn Moehn joined Ameren Services in 2000. In 2008, he was elected senior vice president, corporate planning and business risk management of Ameren Services. In 2012, Moehn relinquished his position at Ameren Services and was elected senior vice president of customer operations of Ameren Illinois. Subsequently in 2012, Moehn relinquished his position at Ameren Illinois and was elected senior vice president, customer operations of Ameren Missouri. Senior Vice President, Customer Operations (Ameren Missouri) 44 Charles D. Naslund Naslund joined Ameren Missouri in 1974. In 2008, he was elected chairman, president and chief executive officer of AER. In 2011, Naslund assumed the position of senior vice president, generation and environmental projects of Ameren Missouri and relinquished his positions of chairman, president and chief executive officer of AER. In 2013, Naslund relinquished his position at Ameren Missouri and was elected senior vice president of Ameren Services. Subsequently in 2013, Naslund was elected executive vice president of Ameren Services and Ameren Missouri. Executive Vice President (Ameren Missouri) 61 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 the executive officers and any directors of the Ameren Companies. All of the above-named executive officers have been employed by an Ameren company for more than five years in executive or management positions. 27 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 57,623 on January 31, 2014. The following table presents the price ranges, closing prices, and dividends declared per Ameren common share for each quarter during 2013 and 2012. High Low Close Dividends Declared 2013 Quarter Ended: March 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Quarter Ended: March 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 35.12 36.74 36.70 37.31 33.68 34.04 35.30 33.21 $ $ 30.64 32.34 32.61 34.18 30.89 31.15 32.27 28.43 $ $ 35.02 34.44 34.84 36.16 32.58 33.54 32.67 30.72 $ $ 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 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. The following table sets forth the quarterly common stock dividend payments made by Ameren and its registrant subsidiaries during 2013 and 2012: (In millions) Registrant 2013 Quarter Ended 2012 Quarter Ended December 31 September 30 June 30 March 31 December 31 September 30 June 30 March 31 Ameren Missouri . . . . . . . . . . Ameren Illinois . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . $ 140 65 97 $ 140 15 97 $ 90 15 97 $ 90 15 97 $ 100 57 98 $ 100 57 97 $ 100 38 97 $ 100 37 90 On February 14, 2014, the board of directors of Ameren declared a quarterly dividend on Ameren’s common stock of 40 cents per share. The common share dividend is payable March 31, 2014, to shareholders of record on March 12, 2014. For a discussion of restrictions on the Ameren Companies’ payment of dividends, see Liquidity and Capital Resources in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report. Purchases of Equity Securities Ameren, Ameren Missouri, and Ameren Illinois did not purchase equity securities reportable under Item 703 of Regulation S-K during the period from October 1, 2013, to December 31, 2013. 28 Performance Graph The following graph shows Ameren’s cumulative total shareholder return during the five years ended December 31, 2013. The graph also shows the cumulative total returns of the S&P 500 Index and the Edison Electric Institute Index (EEI Index), which comprises most investor-owned electric utilities in the United States. The comparison assumes that $100 was invested on December 31, 2008, in Ameren common stock and in each of the indices shown, and it assumes that all of the dividends were reinvested. $250 $200 $150 $100 $50 2008 2009 2010 2011 2012 2013 Ameren S&P 500 Index EEI Index December 31, 2008 2009 2010 2011 2012 2013 Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S&P 500 Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . EEI Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 100.00 100.00 100.00 $ 89.29 126.46 110.71 $ 95.41 145.50 118.50 $ 118.07 148.58 142.19 $ 115.09 172.35 145.16 $ 141.91 228.17 164.05 Ameren management cautions that the stock price performance shown in the graph above should not be considered indicative of potential future stock price performance. 29 ITEM 6. SELECTED FINANCIAL DATA For the years ended December 31, (In millions, except per share amounts) Ameren(a): 2013 2012 2011 2010 2009 Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (loss) from discontinued operations, net of taxes(c) . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . Common stock dividends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Continuing operations earnings per share – basic . . . . . . . . . . . . . . . . . . . Continuing operations earnings per share – diluted . . . . . . . . . . . . . . . . . Common stock dividends per share . . . . . . . . . . . . . . . . . . . . . . . . . . . . . As of December 31: Total assets(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, excluding current maturities . . . . . . . . . . . . . . . . . . . . . . Total Ameren Corporation stockholders’ equity . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income available to common stockholder . . . . . . . . . . . . . . . . . . . . . . Dividends to parent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . As of December 31: Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, excluding current maturities . . . . . . . . . . . . . . . . . . . . . . Total stockholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income available to common stockholder . . . . . . . . . . . . . . . . . . . . . . Dividends to parent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . As of December 31: Total assets(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, excluding current maturities . . . . . . . . . . . . . . . . . . . . . . Total stockholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ $ $ $ $ $ $ 5,838 1,184 518 (223) 289 388 2.11 2.10 1.60 21,042 5,504 6,544 3,541 803 395 460 12,904 3,648 3,993 2,311 415 160 110 7,454 1,856 2,448 $ $ $ $ $ $ 5,781 1,188 522 (1,496) (974) 382 2.13 2.13 1.60 22,230 5,802 6,616 3,272 845 416 400 13,043 3,801 4,054 2,525 377 141 189 7,282 1,577 2,401 6,148 1,033 437 89 519 375 1.79 1.79 1.555 23,723 5,853 7,919 3,383 609 287 403 12,757 3,772 4,037 2,787 458 193 327 7,213 1,657 2,452 $ $ $ $ $ $ 6,188 1,175 523 (372) 139 368 2.15 2.15 1.54 23,511 6,029 7,730 3,197 711 364 235 12,504 3,949 4,153 3,014 498 248 133 7,406 1,657 2,576 $ $ $ $ $ $ 5,811 890 369 255 612 338 1.63 1.63 1.54 23,701 6,287 7,856 2,874 566 259 175 12,219 4,018 4,057 2,984 363 241 98 8,298 1,847 3,072 Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Includes “Taum Sauk regulatory disallowance” of $89 million recorded at Ameren and Ameren Missouri for the year ended December 31, 2011. (a) (b) (c) See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information. (d) Includes total assets from discontinued operations of $165 million, $1,611 million, $3,721 million, $3,825 million, and $4,593 million at December 31, 2013, 2012, 2011, 2010, and 2009, respectively. Includes total assets from discontinued operations (AERG) of $1,117 million at December 31, 2009. (e) 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 under PUHCA 2005, administered by FERC. Ameren’s 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 other expenses by Ameren depend on distributions made to it by its subsidiaries. Below is a summary description of Ameren Missouri and Ameren Illinois. A more detailed description can be found in Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. ‰ and a rate-regulated natural gas transmission and distribution business in Missouri. Ameren Illinois operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. Ameren has various other subsidiaries responsible for activities such as the provision of shared services. Ameren also has a subsidiary, ATXI, that operates a FERC rate- regulated electric transmission business and is developing the Illinois Rivers project. The Illinois Rivers project is a MISO-approved project to build a 345-kilovolt line from western Indiana across the state of Illinois to eastern Missouri at an estimated cost of $1.1 billion. ‰ Ameren Missouri operates a rate-regulated electric generation, transmission, and distribution business, On March 14, 2013, Ameren entered into a transaction agreement to divest New AER to IPH. On December 2, 30 2013, Ameren completed the divestiture of New AER to IPH. On January 31, 2014, Medina Valley completed its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information. These divestitures position Ameren to focus exclusively on its rate-regulated electric, natural gas, and transmission operations. As a result of the transaction agreement with IPH and Ameren’s plan to sell its Elgin, Gibson City, and Grand Tower gas-fired energy centers, Ameren determined that New AER and the gas-fired energy centers qualified for discontinued operations presentation beginning March 14, 2013. In addition, as of December 2, 2013, Ameren abandoned the Meredosia and Hutsonville energy centers upon the completion of the divestiture of New AER to IPH. Ameren is prohibited from operating these energy centers through December 31, 2020, as a provision of the Illinois Pollution Control Board’s November 2013 order granting IPH a variance of the MPS. As a result, Ameren determined that the Meredosia and Hutsonville energy centers qualified for discontinued operations presentation as of December 2, 2013. The Meredosia and Hutsonville energy centers ceased operations at December 31, 2011, and therefore 2011 was the last year those energy centers had a material effect on Ameren’s consolidated financial statements. As a result of these events, Ameren has segregated New AER’s and the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers’ operating results, assets, and liabilities and presented them separately as discontinued operations for all periods presented in this report. Unless otherwise stated, the following sections of Management’s Discussion and Analysis of Financial Condition and Results of Operations exclude discontinued operations for all periods presented. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information regarding that presentation. The financial statements of Ameren are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. Ameren Missouri and Ameren Illinois have no subsidiaries, and therefore their financial statements are not prepared on a consolidated basis. All significant intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated. In addition to presenting results of operations and earnings amounts in total, we present certain information in cents per share. These amounts reflect factors that directly affect Ameren’s earnings. We believe that this per share information helps readers to understand the impact of these factors on Ameren’s earnings per share. All references in this report to earnings per share are based on average diluted common shares outstanding. OVERVIEW With its exit from the merchant generation business complete, Ameren is focused exclusively on its rate- regulated utilities. Ameren plans to invest in and operate its utilities in a manner consistent with existing regulatory frameworks, optimizing operating and capital spending within these frameworks, including managing costs in a disciplined manner. As a result, Ameren intends to allocate significant and increasing amounts of discretionary capital to FERC-regulated electric transmission service and Illinois electric delivery service projects because these services operate under formulaic and constructive regulatory frameworks. Ameren Missouri expects to file an electric service rate case in July 2014. The rate case is expected to include the costs associated with the completion of two significant capital projects, which projects are the replacement of the nuclear reactor head at Ameren Missouri’s Callaway energy center and upgrades to precipitators at Ameren Missouri’s coal-fired Labadie energy center. Both of these projects are scheduled for completion during the fourth quarter of 2014. The timing of the rate case filing is designed to minimize, to the extent possible under the existing regulatory framework, the regulatory lag on these two important capital investments. Ameren Missouri continues to seek a regulatory framework with reduced regulatory lag, which provides timely cash flows and a reasonable opportunity to earn fair returns on investments that are in the best long-term interest of its customers. An enhanced regulatory framework would increase Ameren Missouri’s ability to reinvest discretionary capital in aging energy infrastructure. Ameren Illinois continues to participate in the IEIMA’s performance-based formula ratemaking framework for electric delivery service. Under this framework, the ICC issued an order in December 2013 which approved a net $45 million reduction in Ameren Illinois’ electric delivery service rates used for 2014 customer billings, compared with 2013. The reduction was primarily caused by a $68 million refund due to customers in 2014 as a result of the 2012 revenue requirement reconciliation, partially offset by a $23 million increase in recoverable costs. These rates will affect Ameren Illinois’ cash flows during 2014, but not its operating revenues, which will instead be determined by the IEIMA’s 2014 revenue requirement reconciliation. In 2013, Illinois enacted into law certain amendments to the IEIMA that modified its implementation, which were consistent with Ameren Illinois’ view of the IEIMA’s performance-based formula rate framework. In December 2013, the ICC issued a rate order that approved an increase in revenues for natural gas delivery service of $32 million, based on a 2014 future test year, with rates that became effective January 1, 2014. Also in 2013, Illinois enacted legislation that encourages Illinois natural gas utilities to accelerate modernization of the state’s natural gas infrastructure and provides for additional 31 ICC oversight of natural gas utility performance. The law provides for a rate rider mechanism to recover costs of certain natural gas infrastructure investments made between rate cases. Ameren Illinois expects to begin including investments under this regulatory framework in 2015. Over the next five years, Ameren plans to invest $2.25 billion in FERC-regulated electric transmission projects (ATXI – $1.4 billion; Ameren Illinois – $850 million). In 2013, ATXI obtained a certificate of public convenience and necessity from the ICC approving portions of its Illinois Rivers transmission project. In February 2014, the ICC issued a final order on rehearing approving the remaining substations and routes of the project. The Illinois Rivers project has an estimated total project cost of $1.1 billion. A full range of construction activities for the Illinois Rivers project is scheduled in 2014. The Ameren Illinois transmission investments are local reliability projects. Earnings Ameren reported net income of $289 million, or $1.18 per diluted share, for 2013, compared with net loss of $974 million, or a loss of $4.01 per diluted share, in 2012. Net income attributable to Ameren Corporation from continuing operations was $512 million, or $2.10 per diluted share, for 2013, and $516 million, or $2.13 per diluted share, for 2012. Ameren’s earnings from continuing operations decreased in 2013, compared with 2012, in part, because of reduced earnings at Ameren Missouri due to the costs of the Callaway energy center’s 2013 scheduled refueling and maintenance outage, compared with 2012 when there was no refueling outage, a reduction in revenues resulting from a MoPSC order related to the FAC, and the absence in 2013 of a 2012 benefit from a FERC- ordered refund from Entergy. Additionally, earnings from continuing operations were unfavorably affected by decreased electric demand resulting from 2013 summer temperatures that were cooler than warmer-than-normal 2012 temperatures partially offset by increased electric and natural gas demand resulting from winter temperatures in 2013 that were colder than winter temperatures in 2012. Earnings from continuing operations were also unfavorably affected by the ICC’s December 2013 order that resulted in a charge to earnings for the ICC’s disallowance of a portion of debt premium costs. Net income from continuing operations at Ameren was favorably affected in 2013, compared with 2012, by rate increases for Ameren Missouri electric and Ameren Illinois transmission services, both effective in January 2013, as well as higher Ameren Illinois electric delivery service earnings. The latter reflected the absence, in 2013, of a 2012 required IEIMA contribution to the Illinois Science and Energy Innovation Trust, as well as increased rate base and a higher allowed return on equity due to higher 30-year United States Treasury bond yields under formula ratemaking. During 2013, Ameren Missouri and Ameren Illinois continued to align spending with regulatory outcomes, policies, and economic conditions. Liquidity Cash flows from operations associated with continuing operations of $1.6 billion and available cash on hand were used to pay dividends to common stockholders of $388 million and to fund capital expenditures of $1.4 billion. At December 31, 2013, Ameren, on a consolidated basis, had available liquidity, in the form of cash on hand and amounts available under existing credit agreements, of approximately $1.7 billion. Capital Spending In 2013, Ameren made significant investments in its utilities and expects that trend to continue into the foreseeable future. From 2014 through 2018, Ameren’s cumulative capital spending is projected to range between $8 billion and nearly $9 billion. The spending includes approximately $1.4 billion for ATXI’s investment in its electric transmission assets. RESULTS OF OPERATIONS Our results of operations and financial position are affected by many factors. Weather, economic conditions, and the actions of key customers can significantly affect the demand for our services. Our results are also affected by seasonal fluctuations: winter heating and summer cooling demands. The vast majority of Ameren’s revenues are subject to state or federal regulation. This regulation has a material impact on the prices we charge for our services. We principally use coal, nuclear fuel, natural gas, methane gas, and oil for fuel in our operations. The prices for these commodities can fluctuate significantly because of the global economic and political environment, weather, supply and demand, and many other factors. We have natural gas cost recovery mechanisms for our Illinois and Missouri natural gas delivery service businesses, a purchased power cost recovery mechanism for our Illinois electric delivery service business, and a FAC for our Missouri electric utility business. Ameren Illinois’ electric delivery service utility business, pursuant to the IEIMA, conducts an annual reconciliation of the revenue requirement necessary to reflect the actual costs incurred in a given year with the revenue requirement that was in effect for that year, with recoveries from or refunds to customers made in a subsequent year. Included in Ameren Illinois’ revenue requirement reconciliation is a formula for the return on equity, which is equal to the average of the monthly yields of 30-year United States treasury bonds plus 580 basis points. Therefore, Ameren Illinois’ annual return on equity will be directly correlated to yields on United States treasury bonds. Fluctuations in interest rates and conditions in the capital and credit markets also affect our cost of borrowing and our pension and postretirement benefits costs. We employ various risk management strategies to reduce our exposure to commodity risk and other risks inherent in our business. The reliability of our energy centers and transmission and distribution systems and the level of purchased power costs, operations and maintenance costs, and capital investment are key factors that we seek to control to optimize our results of operations, financial position, and liquidity. 32 Earnings Summary The following table presents a summary of Ameren’s earnings for the years ended December 31, 2013, 2012, and 2011: 2013 2012 2011 Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . $ 289 $ (974) $ 519 Earnings (loss) per common share – diluted . . . . . . . . . . . . . . . . . . . . . . . . . . 1.18 (4.01) 2.15 Net income attributable to Ameren Corporation – continuing operations . . . 512 516 431 Earnings per common share – diluted – continuing operations . . . . . . . . . . . . . . 2.10 2.13 1.79 2013 versus 2012 Net income attributable to Ameren Corporation from continuing operations in 2013 decreased $4 million, or $0.03 per diluted share, from 2012. Net income attributable to Ameren Corporation decreased in the Ameren Missouri segment by $21 million, partially offset by an increase in the Ameren Illinois segment of $19 million. Compared with 2012 earnings per share from continuing operations, 2013 earnings per share from continuing operations were unfavorably affected by: ‰ ‰ ‰ ‰ ‰ ‰ the cost of the Callaway energy center’s scheduled refueling and maintenance outage in 2013. There was no Callaway refueling and maintenance outage in 2012 (10 cents per share); a reduction in Ameren Missouri revenues resulting from a July 2013 MoPSC order that required a refund to customers for the earnings associated with certain long-term partial requirements sales recognized from October 1, 2009, to May 31, 2011 (7 cents per share); the absence in 2013 of a reduction in Ameren Missouri’s purchased power expense and an increase in interest income, each as a result of a FERC-ordered refund received in 2012 from Entergy for a power purchase agreement that expired in 2009 (7 cents per share); decreased electric demand resulting from summer temperatures in 2013 that were cooler than the warmer-than-normal temperatures in 2012, partially offset by increased electric and natural gas demand resulting from winter temperatures in 2013 that were colder than winter temperatures in 2012 (6 cents per share); the ICC’s December 2013 orders disallowing recovery from customers of a portion of the premium paid by Ameren Illinois for a tender offer in August 2012 to repurchase outstanding senior secured notes (4 cents per share); and increased depreciation primarily due to infrastructure additions at Ameren Missouri and Ameren Illinois and Ameren Illinois’ new electric depreciation rates (3 cents per share). Compared with 2012 earnings per share from continuing operations, 2013 earnings per share from continuing operations were favorably affected by: ‰ ‰ ‰ ‰ higher Ameren Missouri utility rates pursuant to an order issued by the MoPSC, which became effective in January 2013, partially offset by increased regulatory asset amortization as directed by the rate order. This excludes MEEIA impacts, which are discussed separately below (12 cents per share); higher revenues associated with Ameren Missouri’s MEEIA program cost and projected lost revenue recovery mechanism (9 cents per share), which were partially offset by lower revenues resulting from reduced demand due to energy efficiency programs; higher electric transmission rates at Ameren Illinois and ATXI (8 cents per share); and an increase in Ameren Illinois’ electric delivery service earnings under formula ratemaking, favorably affected primarily by an increased rate base, a higher allowed return on equity, and lower required contributions pursuant to the IEIMA (8 cents per share). The cents per share information presented above is based on diluted average shares outstanding in 2012. 2012 versus 2011 Net income attributable to Ameren Corporation from continuing operations in 2012 increased $85 million, or $0.34 per diluted share, from 2011. Net income attributable to Ameren Corporation increased in the Ameren Missouri segment by $129 million, which was partially offset by a decrease in the Ameren Illinois segment of $52 million. Compared with 2011 earnings per share from continuing operations, 2012 earnings per share from continuing operations were favorably affected by: ‰ ‰ ‰ ‰ ‰ the absence in 2012 of a 2011 charge for the MoPSC’s July 2011 disallowance of costs of enhancements relating to the rebuilding of Ameren Missouri’s Taum Sauk energy center in excess of amounts recovered from property insurance (23 cents per share); higher utility rates at Ameren Missouri and Ameren Illinois. Ameren Missouri’s electric rates increased pursuant to an order issued by the MoPSC, which became effective in July 2011. The favorable impact of the Ameren Missouri rate increase on earnings was reduced by the increased regulatory asset amortization directed by the rate order. Ameren Illinois’ natural gas rates increased pursuant to an order issued by the ICC, which became effective in mid- January 2012 (22 cents per share); the absence in 2012 of a Callaway energy center refueling and maintenance outage (11 cents per share); the impact of fewer major storms on operations and maintenance expenses (9 cents per share); a reduction in Ameren Missouri’s purchased power expense and an increase in interest income, each as a result of a FERC-ordered refund received in 2012 from Entergy for a power purchase agreement that expired in 2009 (7 cents per share); 33 ‰ ‰ ‰ the absence in 2012 of a 2011 charge associated with voluntary separation offers to eligible Ameren Missouri and Ameren Services employees (7 cents per share); the absence in 2012 of a reduction in Ameren Missouri’s revenues as a result of the MoPSC’s April 2011 FAC prudence review order covering March 1, 2009, to September 30, 2009, which caused Ameren Missouri to record an obligation to refund to its electric customers the earnings associated with certain previously recognized sales (5 cents per share); and a reduction in labor costs because of staff reductions at Ameren Missouri, primarily resulting from the 2011 voluntary separation plan. The favorable effect at Ameren Missouri was partially offset by increased labor costs at Ameren Illinois due to staff additions to comply with the requirements of the IEIMA (2 cents per share). Compared with 2011 earnings from continuing operations, 2012 earnings from continuing operations were unfavorably affected by: ‰ a reduction in Ameren Illinois’ electric earnings primarily caused by a lower allowed return on equity under electric delivery service formula ratemaking and required donations pursuant to the IEIMA (17 cents per share); ‰ ‰ ‰ an increase in Ameren Missouri depreciation and amortization expense caused primarily by the installation of scrubbers at the Sioux energy center (8 cents per share); reduced electric and natural gas demand as a result of warmer 2012 winter temperatures (estimated at 7 cents per share); and reduced rate-regulated retail sales volumes, excluding the effects of abnormal weather, as sales volumes declined due to continued economic pressure, energy efficiency measures, and customer conservation efforts, among other items (2 cents per share). The cents per share information presented above is based on diluted average shares outstanding in 2011. For additional details regarding the Ameren Companies’ results of operations, including explanations of Margins, Other Operations and Maintenance Expenses, Taum Sauk Regulatory Disallowance, Depreciation and Amortization, Taxes Other Than Income Taxes, Other Income and Expenses, Interest Charges, Income Taxes and Income (Loss) from Discontinued Operations, Net of Taxes, see the major headings below. 34 Below is a table of income statement components by segment for the years ended December 31, 2013, 2012, and 2011: 2013 Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income and (expenses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (taxes) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (loss) from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Loss from discontinued operations, net of taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income attributable to noncontrolling interests – continuing operations . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income and (expenses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (taxes) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (loss) from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Loss from discontinued operations, net of taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income attributable to noncontrolling interests – continuing operations . . . . . . . . . . . . . Net loss attributable to noncontrolling interests – discontinued operations . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 Electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other operations and maintenance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taum Sauk regulatory disallowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes other than income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income and (expenses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (taxes) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (loss) from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income from discontinued operations, net of taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income attributable to noncontrolling interests – continuing operations . . . . . . . . . . . . . Net income attributable to noncontrolling interests – discontinued operations . . . . . . . . . . . Ameren Missouri Ameren Illinois Other / Intersegment Eliminations $ $ $ $ $ $ $ $ $ $ 2,407 83 1 (915) (454) (319) 47 (210) (242) 398 - 398 (3) 395 2,340 75 1 (827) (440) (304) 49 (223) (252) 419 - 419 (3) - 416 2,252 79 5 (934) (89) (408) (296) 51 (209) (161) 290 - 290 (3) - 1,081 399 3 (693) (243) (132) 1 (143) (110) 163 - 163 (3) 160 1,034 378 - (684) (221) (130) (10) (129) (94) 144 - 144 (3) - $ $ $ (3) (2) (4) (9) (9) (7) (5) (45) 41 (43) (223) (266) - (266) (11) (1) (1) - (12) (9) (6) (40) 39 (41) (1,496) (1,537) - 6 141 $ (1,531) $ 1,087 354 1 (640) - (215) (129) 1 (136) (127) 196 - 196 (3) - (10) (2) (6) 12 - (20) (8) (7) (42) 34 (49) 89 40 - (1) 39 $ $ $ $ $ Total 3,485 480 - (1,617) (706) (458) 43 (398) (311) 518 (223) 295 (6) 289 3,363 452 - (1,511) (673) (443) 33 (392) (307) 522 (1,496) (974) (6) 6 (974) 3,329 431 - (1,562) (89) (643) (433) 45 (387) (254) 437 89 526 (6) (1) $ 519 Net income attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 287 $ 193 $ 35 Margins The following table presents the favorable (unfavorable) variations by segment for electric and natural gas margins from the previous year. Electric margins are defined as electric revenues less fuel and purchased power costs. Natural gas margins are defined as gas revenues less gas purchased for resale. The table covers the years ended December 31, 2013, 2012, and 2011. 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 may not be comparable to other companies’ presentations or more useful than the GAAP information we provide elsewhere in this report. 2013 versus 2012 Ameren Missouri Ameren Illinois Other(a) Ameren Electric revenue change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Base rates (estimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system sales and transmission services revenues (included in base rates) . . . . . . . . . . . . . . . . . Transmission services revenue excluded from FAC until 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recovery of FAC under-recovery(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . FAC prudence review charge . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MEEIA (energy efficiency) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gross receipts tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Illinois pass-through power supply costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hurricane Sandy relief recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bad debt, energy efficiency programs, and environmental remediation cost riders . . . . . . . . . . . . . . Sales volume (excluding the impact of abnormal weather) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenue change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fuel and purchased power change: Energy costs included in base rates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recovery of FAC under-recovery(c) FERC-ordered power purchase settlement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Illinois pass-through power supply costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ (29) 178 11 (32) 67 (25) 72 - 12 - (7) - 4 (4) 247 (89) (67) (24) - Total fuel and purchased power change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (180) Net change in electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Base rates (estimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hurricane Sandy relief recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gross receipts tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales volume (excluding the impact of abnormal weather) and other . . . . . . . . . . . . . . . . . . . . . . . . $ $ Net change in natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 67 3 - - 1 4 8 $ (11) 57 - - - - - 25 - (325) (10) (15) 2 (1) $ (278) $ $ $ $ $ - - - 325 325 47 14 2 (3) 7 1 21 $ $ $ $ $ $ $ - - - - - - - 10 - (2) - - - (2) 6 - - - 2 2 8 - - - - (1) (1) $ $ $ $ $ $ $ (40) 235 11 (32) 67 (25) 72 35 12 (327) (17) (15) 6 (7) (25) (89) (67) (24) 327 147 122 17 2 (3) 8 4 28 36 2012 versus 2011 Ameren Missouri Ameren Illinois Other(a) Ameren Electric revenue change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Base rates (estimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-system sales revenues (included in base rates) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recovery of FAC under-recovery(c) FAC prudence review charge . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wholesale revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Illinois pass-through power supply costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bad debt, energy efficiency programs and environmental remediation cost riders . . . . . . . . . . . . . . Hurricane Sandy relief recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales volume (excluding the impact of abnormal weather) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total electric revenue change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fuel and purchased power change: Energy costs included in base rates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recovery of FAC under-recovery(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net unrealized MTM gains . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . FERC-ordered power purchase settlement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission over-recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Illinois pass-through power supply costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total fuel and purchased power change . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net change in electric margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas margins change: Effect of weather (estimate)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Base rates (estimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rate redesign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Energy efficiency programs and environmental remediation cost riders . . . . . . . . . . . . . . . . . . . . . . Bad debt rider . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hurricane Sandy relief recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales volume (excluding the impact of abnormal weather) and other . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ Net change in natural gas margins . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (19) 102 (131) (47) 17 5 (13) - - 7 (6) (5) $ (1) (55) - - - (1) (6) (154) 7 10 (3) 2 (90) $ (201) $ $ $ $ - - - - (6) 154 148 (53) (10) 20 - 8 (5) 3 8 106 47 1 24 - - 178 88 (2) 2 (5) - - - 1 (4) $ $ $ $ $ $ - - - - - 1 - 2 - - - (2) 1 - - - - - (2) (2) (1) - - - - - - 1 1 $ (20) 47 (131) (47) 17 5 (19) (152) 7 17 (9) (5) $ (290) $ 106 47 1 24 (6) 152 $ $ $ 324 34 (12) 22 (5) 8 (5) 3 10 $ 21 $ 24 $ Includes amounts for other nonregistrant subsidiaries and intercompany eliminations. (a) (b) Represents the estimated margin impact of changes in cooling and heating degree-days on electric and natural gas demand compared with the prior year; this is based on temperature readings from the National Oceanic and Atmospheric Administration weather stations at local airports in our service territories. (c) Represents the change in the net fuel costs recovered under the FAC through customer rates, with corresponding offsets to fuel expense due to the amortization of a previously recorded regulatory asset. 2013 versus 2012 Ameren Corporation Ameren’s electric margins increased by $122 million, or 4%, in 2013 compared with 2012. Ameren’s natural gas margins increased by $28 million, or 6%, in 2013 compared with 2012. These results were primarily driven by Ameren Missouri and Ameren Illinois results, as discussed below. Ameren’s electric margins also reflect the results of operations of ATXI. ATXI’s transmission revenues increased by $10 million in 2013 compared with 2012, due to the inclusion of its 2013 rate base investment in its forward- looking rate calculation. Ameren Missouri Ameren Missouri has a FAC cost recovery mechanism that allows Ameren Missouri to recover, through customer rates, 95% of changes in net energy costs greater or less 37 than the amount set in base rates without a traditional rate proceeding, subject to MoPSC prudence reviews. Net energy cost includes fuel (coal, coal transportation, natural gas for generation, and enriched uranium), certain fuel additives, emission allowances, purchased power costs, transmission costs and revenues, and MISO costs and revenues, net of off-system sales revenues. The MoPSC’s December 2012 electric order authorized the inclusion of fuel additive costs and transmission revenues in the FAC starting in 2013. Ameren Missouri accrues, as a regulatory asset, net energy costs that exceed the amount set in base rates (FAC under-recovery). Net recovery of these costs under the FAC through customer rates increased $67 million, in 2013 compared with 2012, with a corresponding offset to fuel expense to reduce the previously recognized FAC regulatory asset. Ameren Missouri’s electric margins increased by $67 million, or 3%, in 2013 compared with 2012. The following items had a favorable impact on Ameren Missouri’s electric margins: ‰ ‰ ‰ ‰ Higher electric base rates, effective January 2013 as a result of the December 2012 MoPSC electric rate order, which increased revenues by $178 million, partially offset by an increase in net energy costs of $78 million. The increase in net energy costs is the sum of the change in energy costs included in base rates (-$89 million) and the change in off-system sales and transmission services revenues (+$11 million) in the above table. Transmission services revenues were not included in the FAC in 2012 ($32 million). In 2013, transmission services revenues were included in the FAC, but were offset by the increase in base rates. Higher revenues associated with the MEEIA energy efficiency program cost and lost revenue recovery mechanism ($35 million and $37 million, respectively), effective January 2013, which increased revenues by a combined $72 million. The lost revenue recovery mechanism helps compensate Ameren Missouri for lower sales from energy efficiency related volume reductions in current and future periods. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for information regarding Ameren Missouri’s MEEIA energy efficiency program. See Other Operations and Maintenance Expenses in this section for information on a related offsetting increase in energy efficiency program costs. Increased gross receipts taxes, due primarily to the higher base rates, which increased revenues by $12 million. See Taxes Other Than Income Taxes in this section for information on a related offsetting increase to gross receipts taxes. Excluding the estimated impact of abnormal weather, rate-regulated retail sales volumes increased 1%, which increased revenues by $4 million. The following items had an unfavorable impact on Ameren Missouri’s electric margins in 2013 compared with 2012: ‰ ‰ Weather conditions decreased revenues by $29 million. Summer temperatures in 2013 were cooler than the warmer-than-normal temperatures in 2012, as cooling degree-days decreased 22%. However, this was partially offset by winter temperatures in 2013 that were colder than the warmer-than-normal temperatures in 2012, as heating degree-days increased 35%. A reduction in revenues resulting from a July 2013 MoPSC order. Ameren Missouri recorded a FAC prudence review charge for its estimated obligation to refund to its electric customers the earnings associated with sales recognized by Ameren Missouri from October 1, 2009, to May 31, 2011, which decreased revenues by $25 million. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for further information regarding the FAC prudence review charge. ‰ ‰ The absence in 2013 of a reduction in purchased power expense as a result of a FERC-ordered refund received in 2012 from Entergy for a power purchase agreement that expired in 2009, which decreased margins by $24 million. The absence in 2013 of recovery of labor and benefit costs for crews assisting with Hurricane Sandy power restoration in 2012, which decreased margins by $7 million and was fully offset by a related decrease in operations and maintenance costs, with no overall impact on net income. Our costs related to storm assistance are reimbursed by the utilities receiving the assistance. Ameren Missouri’s natural gas margins increased by $8 million, or 11%, in 2013 compared with 2012. The following items had a favorable impact on Ameren Missouri’s natural gas margins: ‰ Excluding the estimated impact of abnormal weather, revenues increased by $4 million, driven by 11% higher natural gas transportation sales and 2% higher retail sales. ‰ ‰ Weather conditions increased revenues by $3 million. Winter temperatures in 2013 were colder than the warmer-than-normal temperatures in 2012, as heating degree-days increased 35%. Increased gross receipts taxes due to higher sales as a result of colder winter weather in 2013 compared with 2012, which increased revenues by $1 million. See Taxes Other Than Income Taxes in this section for information on a related offsetting increase to gross receipts taxes. Ameren Illinois Ameren Illinois has a cost recovery mechanism for power purchased on behalf of its customers. These pass- through power costs do not affect margins. Ameren Illinois’ revenues associated with Illinois pass-through power supply costs decreased because of lower power prices on purchases and reduced volumes caused by customers who switched to alternative retail electric suppliers in 2013. This decrease in revenues was offset by a corresponding decrease in purchased power expense of $325 million. Beginning in 2012, Ameren Illinois elected to participate in the performance-based formula ratemaking framework pursuant to the IEIMA. The IEIMA provides for an annual reconciliation of Ameren Illinois’ electric distribution revenue requirement. As of each balance sheet date, Ameren Illinois records its estimate of the electric distribution revenue impact resulting from the reconciliation of the revenue requirement necessary to reflect the actual recoverable costs incurred for that year with the revenue requirement that was in effect for that year. See Operations and Maintenance Expenses in this section for further information regarding the revenue requirement. If the current year’s revenue requirement is greater than the revenue requirement customer rates were based upon, an increase to electric operating revenues with an offset to a regulatory asset is recorded to reflect the expected recovery 38 of those additional costs from customers within the next two years. If the current year’s revenue requirement is less than the revenue requirement customer rates were based upon, a reduction to electric operating revenues with an offset to a regulatory liability is recorded to reflect the expected refund to customers within the next two years. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for information regarding Ameren Illinois’ revenue requirement reconciliation pursuant to the IEIMA. Ameren Illinois’ electric margins increased by $47 million, or 5%, in 2013 compared with 2012. The following items had a favorable impact on Ameren Illinois’ electric margins: ‰ Electric delivery service formula ratemaking adjustments resulting from the annual reconciliation of the revenue requirement pursuant to the IEIMA, which increased revenues by $57 million. The adjustments were primarily caused by increased rate base, a higher allowed return on equity, and higher recoverable costs. Transmission revenues increased by $25 million due to the implementation of a 2013 forward-looking rate calculation which incorporated the rate base increase in 2013, pursuant to a 2012 FERC order. In 2012, rates were based on a historical period. ‰ The following items had an unfavorable impact on Ameren Illinois’ electric margins in 2013 compared with 2012: ‰ A decrease in recovery of bad debt, energy efficiency program costs, and environmental remediation costs through rate-adjustment mechanisms, which decreased revenues by $15 million. See Other Operations and Maintenance Expenses in this section for information on a related offsetting decrease in bad debt, energy efficiency, and environmental remediation costs. ‰ Weather conditions decreased revenues by $11 million. Summer temperatures in 2013 were cooler than the warmer-than-normal temperatures in 2012, as cooling degree-days decreased 21%. However, this was partially offset by winter temperatures in 2013 that were colder than warmer-than-normal temperatures in 2012, as heating degree-days increased 29%. The absence in 2013 of recovery of labor and benefit costs for crews assisting with Hurricane Sandy power restoration in 2012, which decreased margins by $10 million and was fully offset by a related decrease in operations and maintenance costs, with no overall impact on net income. Our costs related to storm assistance are reimbursed by the utilities receiving the assistance. ‰ Ameren Illinois’ natural gas margins increased by $21 million, or 6%, in 2013 compared with 2012. The following items had a favorable impact on Ameren Illinois’ natural gas margins: ‰ Weather conditions increased revenues by $14 million. Winter temperatures in 2013 were colder than warmer- than-normal temperatures in 2012, as heating degree- days increased 29%. 39 ‰ ‰ Increased gross receipts taxes due to higher sales as a result of colder winter weather in 2013 compared with 2012, which increased revenues by $7 million. See Taxes Other Than Income Taxes in this section for information on a related offsetting increase to gross receipts taxes. Increased natural gas rates effective in late January 2012, which increased revenues by $2 million. Ameren Illinois’ natural gas margins were unfavorably impacted by the absence in 2013 of recovery of labor and benefit costs associated with crews assisting with Hurricane Sandy power restoration in 2012, which decreased margins by $3 million and was fully offset by a related decrease in operations and maintenance costs, with no overall impact on net income. Our costs related to storm assistance are reimbursed by the utilities receiving the assistance. 2012 versus 2011 Ameren Corporation Ameren’s electric margins increased by $34 million, or 1%, in 2012 compared with 2011. Ameren’s natural gas margins increased by $21 million, or 5%, in 2012 compared with 2011. These results were primarily driven by Ameren Missouri and Ameren Illinois results, as discussed below. Ameren Missouri Ameren Missouri has a FAC cost recovery mechanism that allows Ameren Missouri to recover, through customer rates, 95% of changes in net energy costs greater or less than the amount set in base rates without a traditional rate proceeding, subject to MoPSC prudence reviews. Net energy cost includes fuel (coal, coal transportation, natural gas for generation, and enriched uranium), emission allowances, purchased power costs, transmission costs, and MISO costs and revenues, net of off-system sales revenues. The MoPSC’s December 2012 electric order authorized the inclusion of fuel additive costs and transmission revenues in the FAC starting in 2013. Ameren Missouri accrues, as a regulatory asset, net energy costs that exceed the amount set in base rates (FAC under-recovery). Net recovery of these costs under the FAC through customer rates decreased $47 million in 2012 compared with 2011, with a corresponding offset to fuel expense to reduce the previously recognized FAC regulatory asset. Ameren Missouri’s electric margins increased by $88 million, or 4%, in 2012 compared with 2011. The following items had a favorable impact on Ameren Missouri’s electric margins: ‰ Higher electric base rates, effective July 2011 as a result of the 2011 MoPSC electric rate order, which increased revenues by $102 million, partially offset by an increase in net energy costs of $25 million. The increase in net energy costs is the sum of the change in energy costs included in base rates (+$106 million) and the change in off-system sales revenues (-$131 million) in the above table. ‰ ‰ ‰ ‰ ‰ Reduced purchased power expense as a result of a FERC-ordered refund received from Entergy in 2012 relating to a power purchase agreement that expired in 2009, which increased margins by $24 million. The absence in 2012 of a reduction in revenues recorded in 2011 resulting from the MoPSC’s April 2011 FAC prudence review order. Ameren Missouri recorded a FAC prudence review charge of $17 million in 2011 for its estimated obligation to refund to its electric customers the earnings associated with sales recognized during the period from March 1, 2009, to September 30, 2009. The recovery of labor and benefit costs for crews assisting with Hurricane Sandy power restoration, which increased revenues by $7 million and was fully offset by a related increase in operations and maintenance costs, with no overall impact on net income. Higher transmission services revenues, primarily due to two transmission projects that went into service in the second half of 2011 and were included in transmission rates in 2012, which increased revenues by $5 million. Summer temperatures in 2012 were comparable to 2011, as cooling degree-days increased 1%. However, summer temperatures in Ameren Missouri’s service territory in 2012 were the warmest on record with 25% more cooling degree-days than normal. The following items had an unfavorable impact on Ameren Missouri’s electric margins in 2012 compared with 2011: ‰ ‰ Weather conditions decreased revenues by $19 million. Winter temperatures in 2012 were warmer than the near-normal temperatures in 2011, as heating degree- days decreased 16%. The inclusion of wholesale sales in the FAC as an offset to fuel costs beginning July 31, 2011, which decreased revenues by $13 million. Excluding the estimated impact of abnormal weather, rate-regulated retail sales volumes declined by 1%, partially attributable to energy efficiency measures and customer conservation efforts, which decreased revenues by $6 million. ‰ Ameren Missouri’s natural gas margins decreased by $4 million, or 5%, in 2012 compared with 2011. The following items had an unfavorable impact on Ameren Missouri’s natural gas margins: ‰ Rate redesign, implemented as a result of the natural gas delivery service rate order that became effective in late February 2011, which allowed Ameren Missouri to recover more of its non-PGA residential revenues through a fixed monthly charge, with the remaining amounts recovered based on sales volumes, which resulted in revenues being recovered more evenly throughout the year. Revenues decreased by $5 million because the rate redesign was not in effect for the first two months of 2011. 40 ‰ Weather conditions decreased revenues by $2 million. Winter temperatures in 2012 were warmer than the near-normal temperatures in 2011, as heating degree- days decreased 16%. Ameren Missouri’s natural gas margins were favorably affected by an increase in rates that became effective in February 2011, which increased margins by $2 million. Ameren Illinois Ameren Illinois’ revenues associated with Illinois pass- through power supply costs decreased because of lower power prices on purchases and reduced volumes caused by customers who switched to alternative retail electric suppliers. This decrease in revenues was offset by a corresponding decrease in purchased power expense of $154 million. Ameren Illinois’ electric margins decreased by $53 million, or 5%, in 2012 compared with 2011. The following items had an unfavorable impact on Ameren Illinois’ electric margins: ‰ ‰ ‰ ‰ Electric delivery service formula ratemaking adjustment resulting from the annual reconciliation of the revenue requirement pursuant to the IEIMA, which decreased revenues by $55 million. The reduction in revenues for 2012 was primarily caused by a lower allowed return on equity as the ICC’s 2010 electric rate order resulted in a higher return on equity than the 2012 formula rate calculation allowed. The 2012 revenue requirement reconciliation included the impact of the September 2012 ICC order, which reduced revenues from October through December 2012 by $8 million. Lower wholesale distribution revenues, primarily due to lower demand and the recognition of a reserve for revenues subject to a refund as a result of a November 2012 FERC administrative law judge’s decision, which in total decreased revenues by $6 million. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for further information. Ameren Illinois accrues, as a regulatory asset or liability, transmission costs that are greater than or less than the amount set in transmission rates (transmission under-recovery or over-recovery). In 2012, Ameren Illinois over-recovered from customers its transmission costs by $6 million. As a result, Ameren Illinois reduced a previously recognized regulatory asset that had been established for an under- recovery of costs. Excluding the estimated impact of abnormal weather, rate-regulated sales volumes increased by 1%, driven largely by the lower-margin industrial sector. However, margins decreased $3 million due to volume declines in the higher-margin residential and commercial sectors, partially attributable to energy efficiency measures and customer conservation efforts. ‰ Weather conditions decreased revenues by $1 million. Winter temperatures in 2012 were warmer than the near-normal temperatures in 2011 as heating degree- days decreased 14%. The following items had a favorable impact on Ameren Other Operations and Maintenance Expenses Illinois’ electric margins in 2012 compared with 2011: ‰ ‰ ‰ The recovery of labor and benefit costs for crews assisting with Hurricane Sandy power restoration, which increased revenues by $10 million, and was fully offset by operations and maintenance costs, with no overall impact on net income. Increased recovery of bad debt, energy efficiency program costs, and environmental remediation costs through rate-adjustment mechanisms, which increased revenues by $7 million. See Other Operations and Maintenance Expenses in this section for information on the related offsetting increase in bad debt, energy efficiency, and environmental remediation costs. Summer temperatures in 2012 were comparable to 2011, as cooling degree-days increased by 2%. However, summer temperatures in Ameren Illinois’ service territory in 2012 were the warmest on record, with 24% more cooling degree-days than normal. Ameren Illinois’ natural gas margins increased by $24 million, or 7%, in 2012 compared with 2011. The following items had a favorable impact on Ameren Illinois’ natural gas margins: ‰ ‰ ‰ ‰ Higher natural gas rates effective January 2012, which increased revenues by $20 million. Increased recovery of energy efficiency program costs and environmental remediation costs through cost recovery mechanisms, which increased revenues by $8 million. See Other Operations and Maintenance Expenses in this section for information on a related offsetting increase in energy efficiency and environmental remediation costs. Higher sales volume and other primarily due to increased transportation sales from two large industrial customers and 1% higher residential sales volumes, excluding the impact of abnormal weather, which together increased margins by $8 million. The recovery of labor and benefit costs for crews assisting with Hurricane Sandy gas service restoration, which increased revenues by $3 million, and was fully offset by a related increase in operations and maintenance costs, with no overall impact on net income. The following items had an unfavorable impact on Ameren Illinois’ natural gas margins in 2012 compared with 2011: ‰ ‰ Weather conditions decreased revenues by $10 million. Winter temperatures in 2012 were warmer than the near-normal temperatures in 2011, as heating degree- days decreased 14%. Decreased recoveries through the bad debt rider, which reduced margins by $5 million. See Other Operations and Maintenance Expenses in this section for additional information on a related offsetting decrease in bad debt expense. 2013 versus 2012 Ameren Corporation Other operations and maintenance expenses increased by $106 million in 2013 compared with 2012 primarily due to increased expenses at Ameren Missouri and Ameren Illinois as discussed below. Additionally, there was a $9 million increase in unallocated Ameren (parent) other operations and maintenance expenses. Ameren Missouri Other operations and maintenance expenses increased by $88 million in 2013. The following items increased other operations and maintenance expenses between years: ‰ ‰ ‰ ‰ ‰ A $35 million increase in energy efficiency program costs due to the requirements of MEEIA, which became effective in rates in January 2013. These costs were offset by increased electric revenues recovered through customer billings, with no overall effect on net income. A $31 million increase in energy center maintenance costs, primarily due to $38 million in costs for the scheduled 2013 Callaway energy center refueling and maintenance outage. There was no outage in 2012. The 2013 increase was partially offset by a $7 million reduction in costs due to fewer major boiler outages at coal-fired energy centers. A $14 million increase in employee benefit costs, primarily due to higher pension expense and increased amortization of prior-year pension deferrals from the pension and postretirement benefit cost tracker, each as a result of the 2012 MoPSC electric order. These increased employee benefit costs were offset by increased electric revenues from customer billings, with no overall effect on net income. A $9 million increase in storm-related repair costs, primarily due to major storms in 2013. A portion of these costs, $7 million, were offset by electric revenues recovered through customer billings. A $6 million increase in bad debt expense due to reduced customer collections and higher customer rates in 2013. Other operations and maintenance expenses decreased between years because of the absence in 2013 of a $6 million charge recorded in 2012 for a canceled project. Ameren Illinois Pursuant to the provisions of the IEIMA, recoverable electric distribution costs incurred during the year that are not recovered through riders are included in Ameren Illinois’ revenue requirement reconciliation, which results in a corresponding adjustment to electric operating revenues, with no overall effect on net income. These recoverable electric distribution costs include other operations and maintenance expenses, depreciation and amortization, taxes other than income taxes, interest charges, and income taxes. 41 Other operations and maintenance expenses increased by $9 million in 2013. The following items increased other operations and maintenance expenses between years: ‰ An $11 million increase in labor costs, primarily because of staff additions to comply with the requirements of the IEIMA. An $8 million increase in non-storm-related electric distribution maintenance expenditures, primarily related to increased vegetation management work. A $3 million increase in other transmission and distribution expenses, primarily because of expenses for natural gas pipeline integrity compliance. ‰ ‰ The following items decreased other operations and maintenance expenses between years: ‰ A $7 million decrease in bad debt expense due to adjustments under the bad debt rider. Expenses recorded under the Ameren Illinois bad debt rider mechanism were recovered through customer billings, and so were offset by increased revenues, with no overall effect on net income. A $7 million decrease in energy efficiency and environmental remediation costs. These costs were offset by decreased electric and natural gas revenues from customer billings, with no overall effect on net income. 2012 versus 2011 Ameren Corporation Other operations and maintenance expenses decreased by $51 million in 2012 compared with 2011, primarily due to a reduction in Ameren Missouri expenses, which was partially offset by an increase in Ameren Illinois expenses as discussed below. Also, there was a $10 million increase in stock-based compensation expense at Ameren (parent). Ameren Missouri Other operations and maintenance expenses decreased by $107 million in 2012. The following items reduced other operations and maintenance expenses between years: ‰ A $40 million decrease in Callaway energy center refueling and maintenance costs, as there was no outage in 2012. A $27 million decrease in employee severance costs due to the voluntary separation program in 2011. A $25 million reduction in other labor costs, primarily because of staff reductions. A $19 million decrease in storm-related repair costs, due to fewer major storms in 2012. A $6 million favorable change in unrealized net MTM gains between years, resulting from changes in the market value of investments used to support Ameren’s deferred compensation plans. A $6 million decrease in bad debt expense due to improved customer collections. A $4 million decrease in non-storm-related distribution maintenance expenditures, primarily due to lower repair spending. ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ Disciplined cost management efforts to align spending with regulatory outcomes, policies, and economic conditions. Other operations and maintenance expenses increased between years because of a $6 million charge in 2012 for a canceled project. Ameren Illinois Other operations and maintenance expenses increased by $44 million in 2012. The following items increased other operations and maintenance expenses between years: ‰ ‰ ‰ ‰ ‰ A $19 million increase in energy efficiency and environmental remediation costs. These costs were offset by increased electric and natural gas revenues from customer billings, with no overall effect on net income. A $16 million increase in non-storm-related electric distribution maintenance expenditures due, in part, to mild winter weather in 2012 allowing crews to complete more maintenance projects. A $15 million increase in other labor costs, primarily because of staff additions to comply with the requirements of the IEIMA. An $11 million increase in transmission and distribution expenses, primarily because of National Electric Safety Code repairs, which are nonrecoverable operating expenditures under formula ratemaking pursuant to the IEIMA, and pipeline integrity compliance. A $6 million increase in employee benefit costs, primarily due to increased pension expense. The following items reduced other operations and maintenance expenses between years: ‰ ‰ A $14 million decrease in storm-related repair costs, due to fewer major storms in 2012. A $9 million decrease in bad debt expense, including $5 million due to improved customer collections and $4 million due to adjustments under the bad debt rider. Expenses recorded under the Ameren Illinois bad debt rider mechanism were recovered through customer billings, and so were offset by decreased revenues, with no overall effect on net income. Taum Sauk Regulatory Disallowance 2012 versus 2011 Ameren Missouri During 2011, the MoPSC issued an electric rate order that disallowed the recovery of all costs of enhancements, or costs that would have been incurred absent the breach, related to the rebuilding of the Taum Sauk energy center in excess of the amount recovered from property insurance. Consequently, Ameren and Ameren Missouri recorded a pretax charge to earnings of $89 million. 42 Depreciation and Amortization Taxes Other Than Income Taxes 2013 versus 2012 Ameren Corporation 2013 versus 2012 Ameren Corporation Depreciation and amortization expenses increased by $33 million in 2013 compared with 2012 due primarily to increased expenses at Ameren Missouri and Ameren Illinois as discussed below. Taxes other than income taxes increased by $15 million in 2013 compared with 2012 due primarily to increased expenses at Ameren Missouri and Ameren Illinois as discussed below. Ameren Missouri Ameren Missouri Depreciation and amortization expenses increased by Taxes other than income taxes increased by $14 million in 2013 compared with 2012, primarily because of increased depreciation expense of $6 million related to electric distribution capital additions and because of increased amortization expense of $6 million related to the December 2012 MoPSC electric rate order resulting in higher amortization of pre-MEEIA energy efficiency program costs, which were reflected in electric rates effective in January 2013. Ameren Illinois Depreciation and amortization expenses increased by $22 million in 2013 compared with 2012, primarily because of new electric depreciation rates, which increased depreciation expense by $17 million, as a result of a reduction in the useful lives of existing electric meters that are being replaced with advanced metering infrastructure pursuant to the IEIMA, and because of electric general capital additions, which increased depreciation expense by $6 million. $15 million, primarily due to an increase in gross receipts taxes of $13 million as a result of increased sales. These increased gross receipts taxes were offset by increased gross receipts tax revenues, with no overall effect on net income. See Excise Taxes in Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report for additional information. Ameren Illinois Taxes other than income taxes increased by $2 million, primarily because of an increase in gross receipts taxes of $7 million as a result of increased natural gas sales, partially offset by a decrease in property taxes of $6 million, primarily as a result of two electric distribution tax credits received in 2013. The increased gross receipts taxes were offset by increased gross receipts tax revenues, with no overall effect on net income. See Excise Taxes in Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report for additional information. 2012 versus 2011 Ameren Corporation 2012 versus 2011 Ameren Corporation Depreciation and amortization expenses increased by $30 million in 2012 compared with 2011 due to increased expenses at Ameren Missouri and Ameren Illinois as discussed below. There was a $5 million reduction in depreciation and amortization expenses at Ameren Services due to the retirement of computer equipment in 2011. Ameren Missouri Depreciation and amortization expenses increased by $32 million in 2012 compared with 2011, primarily because of increased depreciation and amortization expenses associated with new scrubbers at the Sioux energy center (depreciation expense began with the effective date of the July 2011 electric rate order) and other capital additions. Taxes other than income taxes increased by $10 million in 2012 compared with 2011 due to increased expenses at Ameren Missouri as discussed below. Ameren Missouri Taxes other than income taxes increased by $8 million in 2012, because of higher property taxes resulting from increased state and local assessments in 2012, the recording of a refund for protested distributable taxes in 2011, and the subsequent recording in December 2012 based on the MoPSC electric rate order to return this refund to customers. These unfavorable items more than offset a decrease in payroll taxes between years. Ameren Illinois Depreciation and amortization expenses increased by $6 million in 2012 compared with 2011, primarily because of transmission and distribution infrastructure additions. Taxes other than income taxes were comparable between years, as a reduction in gross receipts taxes resulting from decreased sales offset higher property taxes due to increased rates. Ameren Illinois 43 Other Income and Expenses 2013 versus 2012 Ameren Corporation Interest Charges 2013 versus 2012 Ameren Corporation Other income, net of expenses, increased by $10 million in 2013 compared with 2012 primarily due to decreased expenses at Ameren Illinois as discussed below. Ameren Missouri Other income, net of expenses, decreased by $2 million, primarily due to a decrease in interest income resulting from the absence in 2013 of a 2012 interest payment received from Entergy as part of the FERC-ordered refund related to a power purchase agreement that expired in 2009, partially offset by decreased donations. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for more information about the Entergy refund received in 2012. Ameren Illinois Other income, net of expenses, increased by $11 million, primarily due to decreased donations because of the absence in 2013 of the one-time $7.5 million contribution to the Illinois Science and Energy Innovation Trust pursuant to the IEIMA in connection with participation in the formula ratemaking process in 2012 and to increased interest income, primarily related to the IEIMA’s 2013 revenue requirement reconciliation adjustment. 2012 versus 2011 Ameren Corporation Other income, net of expenses, decreased by $12 million in 2012 compared with 2011 primarily due to increased expenses at Ameren Illinois as discussed below. Ameren Missouri Other income, net of expenses, was comparable between years. Increased donations offset an increase in interest income, resulting from the interest paid by Entergy on the amount it overcharged Ameren Missouri under a power purchase agreement. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for further information on the power purchase agreement with Entergy. Ameren Illinois Ameren Illinois had net other expenses of $10 million in 2012, compared with net other income of $1 million in 2011. Donations increased by $10 million because of a one- time $7.5 million donation and $1 million annual donation to the Illinois Science and Energy Innovation Trust and a $1 million annual donation for customer assistance programs pursuant to the IEIMA, because Ameren Illinois participated in the formula ratemaking process in 2012. Interest charges increased by $6 million in 2013 compared with 2012 because increases at Ameren Illinois more than offset decreases at Ameren Missouri as discussed below. Additionally, there was a $5 million increase in interest charges associated with uncertain tax positions at Ameren (parent). See Note 13 – Income Taxes under Part II, Item 8, of this report for information regarding uncertain tax positions. Ameren Missouri Interest charges decreased by $13 million, primarily because of a decrease in interest charges associated with uncertain tax positions and the favorable net impact of the September 2012 repurchase of $71 million of 6.00% senior secured notes, $121 million of 6.70% senior secured notes, and $57 million of 5.10% senior secured notes and issuance of $485 million of 3.90% senior secured notes. Ameren Illinois Interest charges increased by $14 million, primarily due to a charge recorded in 2013 as a result of the ICC’s December 2013 electric rate order, which disallowed the recovery from customers of a portion of debt premium costs incurred in 2012. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information. Also, interest charges increased due to interest applied to the regulatory liability for the 2012 revenue requirement reconciliation. Partially offsetting the increase was the favorable net impact of the August 2012 repurchase of $87 million of 9.75% senior secured notes and $194 million of 6.25% senior secured notes and issuance of $400 million of 2.70% senior secured notes. 2012 versus 2011 Ameren Corporation Interest charges increased by $5 million in 2012 compared with 2011 primarily because increases at Ameren Missouri more than offset a decrease in interest charges at Ameren Illinois. Additionally, reduced credit facility borrowings and commercial paper issuances at Ameren resulted in a $2 million reduction in interest charges. Ameren Missouri Interest charges increased by $14 million in 2012, primarily because Ameren Missouri no longer recorded an allowance for funds used during construction for pollution control equipment installed at its Sioux energy center after the cost of the equipment was placed in customer rates beginning July 31, 2011, and an increase in interest charges associated with uncertain tax positions. 44 Ameren Illinois Interest charges decreased by $7 million in 2012, primarily because of the redemption of $150 million of senior secured notes in June 2011. Income Taxes The following table presents effective income tax rates for Ameren’s business segments and for the Ameren Companies for the years ended December 31, 2013, 2012, and 2011: Ameren . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . 38% 38% 40% 37% 37% 40% 37% 36% 39% 2013 2012 2011 See Note 13 – Income Taxes under Part II, Item 8, of this report for information regarding reconciliations of effective income tax rates. 2013 versus 2012 Ameren Corporation Ameren’s effective tax rate was higher primarily because of items detailed at Ameren Missouri below. decreased impact of the amortization of property-related regulatory assets and liabilities, and estimated tax credits on higher pretax income in 2012 compared with 2011. Ameren Illinois Ameren Illinois’ effective tax rate was higher primarily because of the favorable impact of recording the adjustment to deferred tax assets due to the Illinois statutory income tax rate increase in 2011. Income (Loss) from Discontinued Operations, Net of Taxes See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for information regarding Ameren’s exit from the Merchant Generation business and the discontinued operations disclosures relating to that business. Ameren’s loss from discontinued operations, net of taxes, was $223 million in 2013, compared with a loss from discontinued operations, net of taxes, of $1.5 billion in 2012. Ameren’s income from discontinued operations, net of taxes, was $89 million in 2011. Ameren’s losses from discontinued operations were impacted by asset impairments in 2011 and 2012, and a loss on disposal in 2013 as discussed below. Ameren Missouri Loss on Disposal Ameren Missouri’s effective tax rate was higher primarily because of the decreased impact of the amortization of property-related regulatory assets and liabilities and an increase in nondeductible expenses, partially offset by an increase in reserves for uncertain tax positions in 2012. Ameren Illinois Ameren Illinois’ effective tax rate was comparable between 2013 and 2012. The increased impact of the amortization of property-related regulatory assets and liabilities was offset by the decreased impact of investment tax credit amortization. 2012 versus 2011 Ameren Corporation Ameren’s effective tax rate was comparable between 2012 and 2011. The effective tax rate increases for Ameren Missouri and Ameren Illinois noted below were offset primarily by a decrease related to permanent tax benefits from company-owned life insurance. Variations in effective tax rates at Ameren Missouri and Ameren Illinois between 2012 and 2011 are noted below. Ameren Missouri Ameren Missouri’s effective tax rate was higher primarily because of an increase in reserves for uncertain tax positions in 2012, compared with a decrease in 2011. Additionally, the effective tax rate increased because of the On March 14, 2013, Ameren entered into a transaction agreement to divest New AER to IPH. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. On January 31, 2014, Medina Valley completed its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital. Upon completion of the divestiture of New AER, Ameren finalized its loss on disposal. Ameren received no cash proceeds from IPH for the divestiture of New AER. Ameren recorded a pretax charge to earnings related to the New AER divestiture of $201 million for the year ended December 31, 2013. The ultimate loss on disposal may differ as a result of the finalization of the working capital adjustment within 120 days of close. In 2013, Ameren adjusted the accumulated deferred income taxes on its consolidated balance sheet to reflect the excess of tax basis over financial reporting basis of its stock investment in AER. This change in basis resulted in a discontinued operations deferred tax expense of $99 million, which was partially offset by the expected tax benefits of $86 million related to the pretax loss from discontinued operations including the loss on disposal, during the year ended December 31, 2013. The final tax basis of the AER disposal group and the related tax benefit resulting from the transaction agreement with IPH are dependent upon the resolution of tax matters under IRS audit, including the adoption of recently issued guidance from the IRS related to tangible property repairs and other matters. As a result, tax expense and benefits ultimately realized in discontinued operations may differ materially from those recorded as of December 31, 2013. 45 As the Elgin, Gibson City, and Grand Tower gas-fired energy center disposal group continued to meet the discontinued operations criteria at December 31, 2013, Ameren evaluated whether any impairment existed by comparing the disposal group’s carrying value to the estimated fair value of the disposal group, less cost to sell. In December 2012, as discussed below, Ameren recorded a noncash long-lived asset impairment charge to reduce the carrying value of AER’s energy centers, including the Elgin, Gibson City, and Grand Tower gas-fired energy centers, to their estimated fair values under the accounting guidance for held and used assets. Ameren did not record any additional impairment relating to the Elgin, Gibson City, and Grand Tower energy centers for the year ended December 31, 2013. On January 31, 2014, Medina Valley completed the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital for a total purchase price of $168 million, before consideration of a net working capital adjustment. Ameren will not recognize a gain from the sale to Rockland Capital for any value in excess of its $137.5 million carrying value for this disposal group since any excess amount that Medina Valley may receive, net of taxes and other expenses, over the carrying value will ultimately be paid to Genco pursuant to the transaction agreement with IPH. Long-lived Asset Impairments Ameren recorded long-lived asset impairments under held and used accounting guidance related to its merchant generation business totaling $2.6 billion in 2012 and $30 million in 2011, before taxes. In December 2012, Ameren concluded that the Merchant Generation segment was no longer a core component of its future business strategy. As a result of the December 2012 decision that Ameren intended to, and that it was probable that it would, exit the Merchant Generation segment before the end of the Merchant Generation long- lived assets’ previously estimated useful lives, Ameren determined that estimated undiscounted cash flows during the period in which it expected to continue to own certain energy centers would be insufficient to recover the carrying value of those energy centers. Accordingly, Ameren recorded a noncash pretax impairment charge of $1.95 billion in December 2012 to reduce the carrying values of all of the Merchant Generation’s coal and natural gas-fired energy centers, except the Joppa coal-fired energy center, to their estimated fair values. The estimated undiscounted cash flows of the Joppa coal-fired energy center exceeded its carrying value; therefore, the Joppa coal-fired energy center was unimpaired. Key assumptions used in the determination of estimated undiscounted cash flows of Ameren’s Merchant Generation segment’s long-lived assets tested for impairment included forward price projections for energy and fuel costs, the expected life or duration of ownership of the long-lived assets, environmental compliance costs and strategies, and operating costs. Those same cash flow assumptions, along with a discount rate and terminal year earnings multiples, were used to estimate the fair value of each energy center. These assumptions are subject to a high degree of judgment and complexity. The fair value estimate of these long-lived assets was based on a combination of the income approach, which considers discounted cash flows, and the market approach, which considers market multiples for similar assets within the electric generation industry. For the fourth quarter 2012 long-lived asset impairment test, Ameren used a discount rate of 10% for the coal-fired energy centers, 10.5% for the combined cycle energy center, and 11.5% for natural gas- fired energy centers, used a terminal year earnings multiple ranging from 4.5 to 6 depending on the energy center’s fuel type and installed pollution control equipment, and estimated that the duration of ownership for each energy center was less than five years, with one energy center’s duration of ownership being less than two years. Holding all other assumptions constant, if the discount rate had been one percentage point higher, or if the terminal year earnings multiple had been one point lower, or if the duration of ownership for each energy center was one year less than estimated, the fourth quarter 2012 impairment charge would have been $30 million to $110 million higher. As discussed above, the Joppa coal-fired energy center’s estimated undiscounted cash flows exceeded its carrying value; however, using the same assumptions to estimate the fair value of that energy center would result in an estimated fair value that approximated its carrying value as of December 31, 2012. In early 2012, the observable market price for power for delivery in that year and in future years in the Midwest sharply declined below 2011 levels, primarily because of declining natural gas prices and the impact of the stay of the CSAPR. As a result of this sharp decline in the market price of power and the related impact on electric margins, Genco decelerated the construction of two scrubbers at its Newton energy center in February 2012. The sharp decline in the market price of power in early 2012 and the related impact on electric margins, as well as the deceleration of construction of Genco’s Newton energy center scrubber project, caused Ameren to evaluate, during the first quarter of 2012, whether the carrying values of Merchant Generation coal-fired energy centers were recoverable. AERG’s Duck Creek energy center’s carrying value exceeded its estimated undiscounted future cash flows. As a result, Ameren recorded a noncash pretax asset impairment charge of $628 million to reduce the carrying value of that energy center to its estimated fair value during the first quarter of 2012. Similar types of assumptions described above for the fourth quarter 2012 long-lived asset impairment test were used in this first quarter 2012 test. In this first quarter 2012 test, Ameren used a discount rate of 9.5% and estimated each energy center’s useful life based on its physical life. The estimated useful life assumption in this first quarter 2012 test was based on energy center specific facts. In December 2011, Genco ceased operations of its Meredosia and Hutsonville energy centers. As a result, Ameren recorded a noncash pretax asset impairment 46 charge of $26 million to reduce the carrying value of the Meredosia and Hutsonville energy centers to their estimated fair values and a $4 million impairment of materials and supplies. LIQUIDITY AND CAPITAL RESOURCES The tariff-based gross margins of Ameren’s rate- regulated utility operating companies are the principal source of cash from operating activities for the Ameren Companies. A diversified retail customer mix primarily of rate-regulated residential, commercial, and industrial customers provide a reasonably predictable source of cash flows for Ameren, Ameren Missouri and Ameren Illinois. In addition to using cash flows from operating activities, Ameren, Ameren Missouri and Ameren Illinois use available cash, credit agreement borrowings, commercial paper issuances, money pool borrowings, or other short-term borrowings from affiliates to support normal operations and other temporary capital requirements. Ameren, Ameren Missouri and Ameren Illinois may reduce their credit agreement or short-term borrowings with cash from operations or, at their discretion, with long-term borrowings, or, in the case of Ameren Missouri and Ameren Illinois, with equity infusions from Ameren. Ameren, Ameren Missouri and Ameren Illinois expect to incur significant capital expenditures over the next five years as they make investments in their electric and natural gas utility infrastructure to support overall system reliability, environmental compliance, and other improvements. Ameren intends to finance those capital expenditures and investments in its rate-regulated businesses with a blend of equity and debt so that it maintains a capital structure in a range around 50% equity, assuming constructive regulatory environments. Ameren, Ameren Missouri and Ameren Illinois plan to implement their long-term financing plans for debt, equity, or equity-linked securities to finance their operations appropriately, to fund scheduled debt maturities, and to maintain financial strength and flexibility. The use of operating cash flows and short-term borrowings to fund capital expenditures and other long- term investments may periodically result in a working capital deficit, as defined by current liabilities exceeding current assets, as was the case at December 31, 2013. The working capital deficit as of December 31, 2013, was primarily the result of current maturities of long-term debt. Ameren is currently evaluating refinancing options for these current maturities including, in part, through the issuance of long-term notes. In addition, Ameren had $368 million of commercial paper issuances outstanding as of December 31, 2013. With the 2012 Credit Agreements, Ameren has access to $2.1 billion of credit capacity of which $1.7 billion was available at December 31, 2013. The following table presents net cash provided by (used in) operating, investing and financing activities for the years ended December 31, 2013, 2012, and 2011: Net Cash Provided By Operating Activities Net Cash (Used In) Investing Activities Net Cash Provided by (Used In) Financing Activities 2013 2012 2011 2013 2012 2011 2013 2012 2011 Ameren(a) – continuing operations . . . . . . . . . . $ Ameren(a) – discontinued operations . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . 1,636 $ 57 1,143 651 1,404 $ 286 1,004 519 1,499 $ 379 1,056 504 (1,440) $ (283) (687) (695) (1,153) $ (157) (703) (437) (949) $ (99) (627) (296) (149) $ - (603) 45 (426) $ - (354) (103) (1,020) (100) (430) (509) (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Cash Flows from Operating Activities 2013 versus 2012 Ameren Corporation Ameren’s cash from operating activities associated with continuing operations increased in 2013, compared with 2012. The following items contributed to the increase in Ameren’s cash from operating activities associated with continuing operations during 2013, compared with 2012: ‰ ‰ The absence in 2013 of $138 million in premiums paid to debt holders in 2012 in connection with the repurchase of the tendered principal of multiple series of Ameren Missouri and Ameren Illinois senior secured notes. A $115 million increase in the cash flows associated with Ameren Missouri’s under-recovered FAC costs. Recoveries outpaced deferrals in 2013 by $41 million, while deferrals and refunds outpaced recoveries in 2012 by $74 million. ‰ ‰ ‰ Electric and natural gas margins, as discussed in Results of Operations, increased by $109 million, excluding impacts of the noncash IEIMA revenue requirement reconciliation adjustment, the under- recovery of MEEIA lost revenues and the MoPSC’s July 2013 order, which resulted in a FAC prudence charge. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for further information. A $94 million increase due to changes in Ameren Missouri coal inventory levels. In 2013, coal inventory levels decreased by $62 million because of delivery disruptions due to flooding, while in 2012, coal inventory levels increased by $32 million primarily because additional tons were held in inventory when generation levels were lower than expected due to market conditions. The absence in 2013 of $25 million in severance payments made in 2012 as a result of the voluntary separation offers extended to Ameren Missouri employees in the fourth quarter of 2011. 47 ‰ ‰ ‰ A $22 million decrease in interest payments, primarily due to 2012 refinancing activity and timing of payments on Ameren Missouri and Ameren Illinois senior secured notes. The receipt of $16 million in 2013 for storm restoration assistance provided to nonaffiliated utilities in 2012 at Ameren Illinois. A one-time $7.5 million contribution, in 2012, by Ameren Illinois to the Illinois Science and Energy Innovation Trust, as required by the IEIMA, which was not repeated in 2013. The following items partially offset the increase in ‰ ‰ ‰ ‰ Ameren’s cash from operating activities associated with continuing operations during 2013, compared with 2012: ‰ A $106 million increase in income tax payments for continuing operations. As discussed below, income tax payments at Ameren Missouri increased $89 million while income tax refunds at Ameren Illinois increased $1 million. Considering both Ameren’s continuing and discontinued operations, Ameren made immaterial federal income tax payments in 2013. A $91 million increase in accounts receivable balances to reflect the timing of revenues earned, but not yet collected, from customers. A $27 million increase in payments for the 2013 scheduled nuclear refueling and maintenance outage at the Callaway energy center. There was no refueling and maintenance outage in 2012. The absence in 2013 of court registry receipts and payments. In 2012, Ameren Missouri received $19 million from the Circuit Court of Stoddard County’s registry and the Circuit Court of Cole County’s registry, net of payments into those registries, as a result of a Missouri Court of Appeals ruling upholding the MoPSC’s January 2009 electric rate order. A $13 million increase in property tax payments, primarily at Ameren Missouri, caused by the timing of payments. A $12 million increase in major storm restoration costs. An $11 million increase in labor costs primarily related to increased staffing levels associated with IEIMA at Ameren Illinois. An $8 million increase in pension and postretirement benefit plan contributions primarily caused by an increase in funding requirements in 2013 compared with 2012, partially offset by an additional postretirement contribution in 2012 at Ameren Illinois. In addition to the Ameren Missouri and Ameren Illinois amounts discussed below, Ameren’s nonregistrant subsidiaries increased their contributions to the pension and postretirement benefit plans by $19 million. Ameren’s cash from operating activities associated with discontinued operations decreased in 2013, compared with 2012, primarily because of a $277 million decrease in electric margins, excluding impacts of noncash unrealized MTM activity. The decrease was partially offset by a $99 million increase in income tax refunds in 2013 due to a reduction in pretax book income partially offset by a reduction in accelerated depreciation deductions. Ameren’s ‰ ‰ ‰ discontinued operations entities received these income tax refunds through the tax allocation agreement with Ameren’s continuing operations entities. Ameren Missouri Ameren Missouri’s cash from operating activities increased in 2013, compared with 2012. The following items contributed to the increase in Ameren Missouri’s cash from operating activities during 2013, compared with 2012: ‰ ‰ ‰ ‰ ‰ ‰ A $115 million increase in the cash flows associated with under-recovered FAC costs. Recoveries exceeded deferrals in 2013 by $41 million, while deferrals and refunds exceeded recoveries in 2012 by $74 million. A $94 million increase due to changes in coal inventory levels. In 2013, coal inventory levels decreased by $62 million because of delivery disruptions due to flooding, while in 2012, coal inventory levels increased by $32 million primarily because additional tons were held in inventory when generation levels were lower than expected due to market conditions. Electric and natural gas margins, as discussed in Results of Operations, increased by $91 million, excluding the impact of the noncash revenues associated with the under-recovery of MEEIA lost revenues and the charge recorded in 2013 associated with the FAC prudence review. The absence in 2013 of $62 million in premiums paid to debt holders in 2012 in connection with the repurchase of the tendered principal of multiple series of senior secured notes. The absence in 2013 of $25 million in severance payments made in 2012 as a result of the voluntary separation offers extended to employees in the fourth quarter of 2011. An $8 million decrease in interest payments, primarily due to 2012 refinancing activity and timing of payments on senior secured notes. The following items partially offset the increase in Ameren Missouri’s cash from operating activities during 2013, compared with 2012: ‰ ‰ ‰ ‰ ‰ Income tax payments totaled $86 million in 2013 resulting primarily from a reduction in accelerated depreciation deductions while income tax refunds were $3 million in 2012. A $60 million increase in accounts receivable balances to reflect the timing of revenues earned, but not yet collected, from customers. A $27 million increase in payments for scheduled nuclear refueling and maintenance outages at the Callaway energy center. There was no refueling and maintenance outage in 2012. A $20 million increase in property tax payments caused by the timing of payments. The absence in 2013 of court registry receipts and payments. In 2012, Ameren Missouri received $19 million from the Circuit Court of Stoddard County’s registry and the Circuit Court of Cole County’s registry, net of payments into those registries, as a result of a 48 Missouri Court of Appeals ruling upholding the MoPSC’s January 2009 electric rate order. A $9 million increase in pension and postretirement benefit plan contributions primarily caused by an increase in funding requirements in 2013 compared with 2012. An $8 million increase in major storm restoration costs. ‰ ‰ Ameren Illinois Ameren Illinois’ cash from operating activities increased in 2013, compared with 2012. The following items contributed to the increase in Ameren Illinois’ cash from operating activities during 2013, compared with 2012: ‰ ‰ ‰ ‰ ‰ ‰ ‰ The absence in 2013 of $76 million in premiums paid to debt holders in 2012 in connection with the repurchase of the tendered principal of multiple series of senior secured notes. A $20 million decrease in pension and postretirement benefit plan contributions primarily caused by an additional postretirement contribution in 2012. The receipt of $16 million in 2013 for storm restoration assistance provided to nonaffiliated utilities in 2012. A $13 million decrease in interest payments, primarily due to 2012 refinancing activity and timing of payments on senior secured notes. Electric and natural gas margins, as discussed in Results of Operations, increased by $11 million, excluding the impact from the noncash IEIMA revenue requirement reconciliation adjustment. A one-time $7.5 million contribution, in 2012, to the Illinois Science and Energy Innovation Trust as required by the IEIMA. A $7 million decrease in property tax payments due to two electricity distribution tax credit refunds received in 2013. The following items partially offset the increase in Ameren Illinois’ cash from operating activities during 2013, compared with 2012: ‰ ‰ A $29 million increase in accounts receivable balances to reflect the timing of revenues earned but not yet collected from customers. An $11 million increase in labor costs primarily related to increased staffing levels associated with IEIMA. 2012 versus 2011 Ameren Corporation Ameren’s cash from operating activities associated with continuing operations decreased in 2012, compared with 2011. The following items contributed to the decrease in cash from operating activities associated with continuing operations during 2012, compared with 2011: ‰ Cash flows associated with Ameren Missouri’s under- recovered FAC costs, which decreased by $161 million. Recoveries exceeded deferrals in 2011 by $87 million, while deferrals exceeded recoveries in 2012 by $74 million. ‰ ‰ ‰ ‰ ‰ The premiums paid to debt holders in connection with the repurchase of the tendered principal of multiple series of Ameren Missouri and Ameren Illinois senior secured notes, which premiums totaled $138 million. See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for further information. An $82 million decrease in cash collections from customer receivables, excluding the impacts of the receipt of funds from, and deposits into, court registries discussed separately below, primarily caused by milder weather in December 2011, compared with December 2010. Income tax payments related to continuing operations of $10 million in 2012, compared with income tax refunds of $47 million in 2011. The 2011 refund resulted primarily from an IRS settlement, while the 2012 payment was caused by the purchase of state tax credits. Ameren did not make material federal income tax payments in either period because of accelerated deductions authorized by economic stimulus legislation and other deductions. A $40 million increase in coal inventory at Ameren Missouri, primarily because additional tons were held in inventory when generation levels were lower than expected due to market conditions, the absence in 2012 of flooding that impeded coal deliveries in 2011, increased coal prices, and milder weather conditions in early 2012. A $22 million increase in energy efficiency expenditures, primarily for Ameren Illinois customer programs, which are recovered through customer billings over time. The following items partially offset the decrease in Ameren’s cash from operating activities associated with continuing operations during 2012, compared with 2011: ‰ ‰ ‰ ‰ ‰ ‰ Electric and natural gas margins, as discussed in Results of Operations, which increased by $111 million, excluding Ameren Illinois’ noncash IEIMA revenue requirement reconciliation adjustment. Ameren Missouri’s receipt of $37 million from the Stoddard County Circuit Court’s registry and the Cole County Circuit Court’s registry as the MoPSC’s 2009 and 2010 electric rate orders were upheld on appeals. Additionally, $24 million fewer Ameren Missouri receivables were paid into the court registries in 2012 in connection with the electric rate order appeals. A $52 million decrease in pension and postretirement plan contributions. In 2011, Ameren Illinois contributed to Ameren’s postretirement benefit plan trust an incremental $100 million in excess of Ameren Illinois’ annual postretirement net periodic cost for regulatory purposes. A $50 million decrease in the cost of natural gas held in storage because of lower prices. A $35 million decrease in major storm restoration costs. A $26 million decrease in taxes other than income tax payments, primarily related to Ameren Missouri, 49 ‰ ‰ ‰ ‰ caused by the timing of property tax payments at each year end, partially offset by higher assessed property tax values. A $21 million reduction in payments for scheduled nuclear refueling and maintenance outages at the Callaway energy center, caused by the absence of a refueling outage in 2012. A $21 million increase in natural gas commodity over- recovered costs under the PGAs, primarily related to Ameren Illinois. A $20 million decrease in payments related to the MISO liability due, in part, to fewer payments required for December 2011 purchases compared to the payments required for December 2010 purchases. A net $5 million decrease in collateral posted with counterparties due, in part, to changes in the market prices of power and natural gas and in contracted commodity volumes. Cash from operating activities associated with discontinued operations decreased in 2012, compared with 2011, primarily because of a $140 million decrease in electric margins, excluding impacts of noncash unrealized MTM activity, partially offset by an $18 million decrease in coal inventory, primarily due to continued focus on inventory reductions, partially offset by increased coal prices. Ameren Missouri Ameren Missouri’s cash from operating activities decreased in 2012 compared with 2011. The following items contributed to the decrease in cash from operating activities during 2012, compared with 2011: ‰ ‰ ‰ ‰ ‰ Cash flows associated with Ameren Missouri’s under- recovered FAC costs, which decreased by $161 million. Recoveries exceeded deferrals in 2011 by $87 million, while deferrals exceeded recoveries in 2012 by $74 million. The premiums paid to debt holders for the repurchase of the tendered principal of multiple series of senior secured notes, which premiums totaled $62 million. A $40 million increase in coal inventory primarily because additional tons were held in inventory when generation levels were lower than expected due to market conditions, the absence in 2012 of flooding that impeded coal deliveries in 2011, increased coal prices, and milder weather conditions in early 2012. A $25 million decrease in cash collections from customer receivables, excluding the receipt of funds from, and deposits into, court registries discussed separately below, primarily caused by milder weather in December 2011, compared with December 2010. A net $6 million increase in collateral posted with counterparties due, in part, to changes in the market price of power and gas and in contracted commodity volumes. The following items partially offset the decrease in Ameren Missouri’s cash from operating activities during 2012, compared with 2011: ‰ Electric and natural gas margins, as discussed in Results of Operations, which increased by $83 million. Receipt of $37 million from the Stoddard County Circuit Court’s registry and the Cole County Circuit Court’s registry as the MoPSC’s 2009 and 2010 electric rate orders were upheld on appeals. Additionally, $24 million fewer Ameren Missouri receivables were paid into the court registries in 2012 in connection with the electric rate order appeals. A $28 million decrease in property tax payments caused by the timing of property tax payments at each year end, partially offset by higher assessed property tax values. A $21 million reduction in payments for scheduled nuclear refueling and maintenance outages at the Callaway energy center. There was no refueling and maintenance outage in 2012. A $20 million decrease in major storm restoration costs. A $15 million reduction in energy efficiency expenditures. Income tax refunds of $3 million in 2012, compared with income tax payments of $9 million in 2011. Ameren Missouri’s 2011 tax liability was reduced by accelerated deductions authorized by economic stimulus legislation, use of its net operating loss carryforwards, and other deductions. Ameren Missouri’s 2012 tax refund is primarily due to a tax deduction related to the repurchase of debt, partially offset by an increase in income from the resolution of the 2009 and 2010 electric rate order appeals discussed above. An $11 million reduction in labor costs due to staff reductions. ‰ ‰ ‰ ‰ ‰ ‰ ‰ Ameren Illinois Ameren Illinois’ cash from operating activities increased in 2012 compared with 2011. The following items contributed to the increase in Ameren Illinois’ cash from operating activities during 2012, compared with 2011: ‰ A $65 million decrease in pension and postretirement benefit plan contributions. In 2011, Ameren Illinois contributed to Ameren’s postretirement benefit plan trust an incremental $100 million in excess of Ameren Illinois’ annual postretirement net periodic cost for regulatory purposes. A $46 million decrease in the cost of natural gas held in storage because of lower prices. Electric and natural gas margins, as discussed in Results of Operations, that increased by $26 million, excluding impacts of the noncash IEIMA revenue requirement reconciliation adjustment. A net $20 million decrease in collateral posted with counterparties due, in part, to changes in the market price of natural gas and in contracted commodity volumes. ‰ ‰ ‰ 50 ‰ ‰ ‰ ‰ ‰ A $20 million decrease in payments related to the MISO liability due, in part, to fewer payments required for December 2011 purchases compared with payments required for December 2010 purchases. A $16 million increase in natural gas commodity over- recovered costs under the PGA. A $15 million decrease in major storm restoration costs. A $12 million decrease in interest payments, primarily due to the redemption of senior secured notes in June 2011. An $8 million increase in income tax refunds primarily due to lower pretax book income along with a tax deduction related to the repurchase of debt. The following items partially offset the increase in Ameren Illinois’ cash from operating activities during 2012, compared with 2011: ‰ ‰ ‰ ‰ ‰ ‰ The premiums paid to debt holders for the repurchase of the tendered principal of multiple series of tendered senior secured notes, which premiums totaled $76 million. A $68 million decrease in cash collections from customer receivables, primarily caused by milder weather in December 2011, compared with December 2010. A $37 million increase in energy efficiency expenditures for customer programs that are recovered through customer billings over time. A $26 million increase in payments to contractors for reliability, maintenance, and IEIMA projects. A $12 million increase in labor costs, primarily because of staff additions due to the requirements of the IEIMA. A one-time $7.5 million payment to the Illinois Science and Energy Innovation Trust, as required by the IEIMA. Pension and Postretirement Plans Ameren’s pension plans are funded in compliance with income tax regulations and to meet federal funding or regulatory requirements. As a result, Ameren expects to fund its pension plans at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering Ameren’s assumptions at December 31, 2013, its investment performance in 2013, and its pension funding policy, Ameren expects to make annual contributions of $20 million to $100 million in each of the next five years, with aggregate estimated contributions of $270 million. We expect Ameren Missouri’s and Ameren Illinois’ portion of the future funding requirements to be 52% and 47%, respectively. These amounts are estimates. The estimates may change with actual investment performance, changes in interest rates, changes in our assumptions, changes in government regulations, and any voluntary contributions. In 2013, Ameren contributed $156 million to its pension plans. See Note 11 – Retirement Benefits under Part II, Item 8, of this report for additional information. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. In accordance with the transaction agreement, Ameren retained the pension obligations as of December 2, 2013, associated with the current and former employees of New AER and its subsidiaries who were included in the Ameren Retirement Plan and the Ameren Supplemental Retirement Plan. Ameren also retained the postretirement benefit obligations associated with the employees of New AER and its subsidiaries who were eligible to retire at December 2, 2013, from the Ameren Retiree Medical Plan and the Ameren Group Life Insurance Plan. IPH assumed the existing pension and other postretirement benefit obligations associated with EEI’s current and former employees that are included in EEI’s single-employer pension and other postretirement plans. Coincident with Ameren’s divestiture of New AER, a significant number of employees left Ameren which required a measurement of Ameren’s pension and postretirement benefit plan assets and obligations as of December 2, 2013, based upon current market conditions. The reduction in obligations for the postretirement benefit plans and the accelerated recognition of gains previously recorded in accumulated other comprehensive income that had not previously been recognized through net periodic benefit cost for the pension and postretirement benefit plans resulted in a $19 million pretax curtailment gain, which was included in discontinued operations. Ameren completed another measurement as of December 31, 2013, as is its historical accounting practice, based upon the market conditions at the end of the year. Excluding the EEI plans, which were assumed by IPH during 2013, Ameren’s unfunded obligation under its pension and other postretirement benefit plans was $461 million and $1,143 million as of December 31, 2013, and December 31, 2012, respectively. The primary factors contributing to this unfunded obligation reduction during 2013 were a 75 basis point increase in the pension and other postretirement benefit plan discount rates used to determine the present value of the obligations, and asset returns being better than expected. The offset to the unfunded obligation reduction was primarily a reduction to regulatory assets. Cash Flows from Investing Activities 2013 versus 2012 Ameren’s cash used in investing activities associated with continuing operations increased by $287 million during 2013, compared with 2012. Capital expenditures increased $316 million, primarily because of increased expenditures for transmission in Illinois, reliability projects, and storm restoration costs. The increase in cash flows used in investing activities was partially offset by a $46 million decrease in nuclear fuel expenditures due to timing of purchases. Cash used in investing activities associated with Ameren’s discontinued operations increased $126 million during 2013, compared with 2012, primarily due to the requirement to leave cash of $235 million with New AER upon divestiture, pursuant to the transaction agreement with IPH. This use of cash was partially offset by reduced capital 51 expenditures in 2013 as a result of the deceleration of the scrubber construction project at the Newton energy center. $9 million receipt from a settlement with the DOE related to nuclear waste disposal. Ameren Missouri’s cash used in investing activities decreased $16 million during 2013, compared with 2012, primarily due to changes in money pool advances and a $46 million decrease in nuclear fuel expenditures due to timing of purchases. The decrease in cash used in investing activities was partially offset by increased capital expenditures and the absence in 2013 of a 2012 receipt of $18 million for federal tax grants related to renewable energy construction projects. Capital expenditures increased $53 million, primarily because of increased expenditures for reliability projects and an increase in storm restoration costs. Ameren Illinois’ cash used in investing activities increased $258 million during 2013, compared with 2012. Capital expenditures increased $259 million, primarily due to increased expenditures of $164 million for transmission and reliability projects, $18 million for storm restoration costs, and $12 million for IEIMA projects. 2012 versus 2011 Ameren’s cash used in investing activities associated with continuing operations increased by $204 million during 2012, compared with 2011. Capital expenditures increased $182 million primarily because of increased expenditures for reliability, boiler, and turbine projects, which more than offset a decrease in storm restoration costs. Cash used in investing activities also increased because of a $29 million increase in nuclear fuel expenditures due to timing of purchases, which was partially offset by a receipt of $18 million of federal tax grants related to renewable energy construction projects. Cash used in investing activities associated with discontinued operations increased $58 million during 2012, compared with 2011. Capital expenditures increased $26 million as a result of increased expenditures related to the scrubber project at the Newton energy center, which more than offset a reduction in maintenance and upgrade project expenditures due to the timing of energy center outages. In 2012, proceeds of $16 million were received from the sale of the Medina Valley energy center’s net property and plant. In 2011, Genco received $45 million of proceeds from the sale of its interest in the Columbia CT energy center. Ameren Missouri’s cash used in investing activities increased $76 million during 2012, compared with 2011. Capital expenditures increased $45 million primarily because of increased expenditures for reliability, boiler, and turbine projects, which more than offset a decrease in storm restoration costs. Cash used in investing activities also increased due to a $29 million increase in nuclear fuel expenditures due to timing of purchases for the spring 2013 reload. In 2012, cash flows from investing activities benefited from $18 million of federal tax grants received related to renewable energy construction projects. In 2011, cash flows used in investing activities benefited from a Ameren Illinois’ cash used in investing activities increased $141 million during 2012, compared with 2011. Capital expenditures increased $91 million as a result of increased expenditures for reliability projects, including $27 million for IEIMA projects, which more than offset a decrease in storm restoration costs. In 2011, cash from investing activities benefited from repayments of advances previously paid to ATXI as a result of the completion of a project under a joint ownership agreement. Capital Expenditures The following table presents the capital expenditures by the Ameren Companies for the years ended December 31, 2013, 2012, and 2011: 2013 2012 2011 Ameren(a) . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . $ 1,379 648 701 $ 1,063 595 442 $ 881 550 351 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and the elimination of intercompany transfers. Ameren’s 2013 capital expenditures consisted of the following expenditures at its subsidiaries. Ameren Missouri spent $53 million on Labadie precipitator upgrades, $30 million on storm restoration, and $29 million on the replacement of the Callaway nuclear reactor head scheduled to be replaced during the 2014 refueling and maintenance outage. Ameren Illinois spent $269 million on transmission initiatives, $39 million on IEIMA projects, and $23 million on storm restoration. ATXI spent $51 million on the Illinois Rivers project. Other capital expenditures were made principally to maintain, upgrade, and expand the reliability of the transmission and distribution systems of Ameren Missouri and Ameren Illinois, as well as to fund various Ameren Missouri energy center upgrades. Ameren’s 2012 capital expenditures consisted of the following expenditures at its subsidiaries. Ameren Missouri spent $30 million on the replacement of the Callaway nuclear reactor head, scheduled to be replaced during the 2014 refueling and maintenance outage and $23 million on a boiler upgrade project. Ameren Illinois spent $27 million on IEIMA projects. Other capital expenditures were made principally to maintain, upgrade, and expand the reliability of the transmission and distribution systems of Ameren Missouri and Ameren Illinois, as well as to fund various Ameren Missouri energy center upgrades. Ameren’s 2011 capital expenditures consisted of the following expenditures at its subsidiaries. Ameren Missouri spent $24 million on building its Maryland Heights energy center and $31 million on storm-related repair costs. Ameren Illinois incurred storm-related repair costs of $20 million. Other capital expenditures were made principally to maintain, upgrade, and expand the reliability 52 of the transmission and distribution systems of Ameren Missouri and Ameren Illinois, as well as to fund various Ameren Missouri energy center upgrades. The following table presents Ameren’s estimated capital expenditures that will be incurred from 2014 through 2018, including construction expenditures, allowance for funds used during construction for Ameren’s rate-regulated utility businesses, and expenditures for compliance with known and existing environmental regulations. Ameren expects to allocate more of its discretionary capital expenditures to Ameren Illinois and ATXI based on their regulatory frameworks. 2014 2015 - 2018 Total Ameren Missouri . . . $ Ameren Illinois . . . . . . . . . . . . . . . . ATXI . . . . . . . . . . Other(a) 760 $ 2,495 - $ 2,740 $ 3,255 - $ 3,500 3,660 2,860 800 1,440 1,200 240 100 75 25 2,600 - 1,110 - 70 - 3,400 - 1,350 - 95 - Ameren . . . . . . . . . . $ 1,825 $ 6,275 - $ 6,875 $ 8,100 - $ 8,700 (a) Includes the elimination of intercompany transfers. Ameren Missouri’s estimated capital expenditures include transmission, distribution, and generation-related investments, as well as expenditures for compliance with environmental regulations. Ameren Illinois’ estimated capital expenditures are primarily for electric and natural gas transmission and distribution-related investments, and estimated capital expenditures incremental to historical average electric delivery capital expenditures to modernize its distribution system pursuant to the IEIMA. Estimated capital expenditures for ATXI include the three MISO- approved multi-value transmission projects. For additional information regarding the IEIMA capital expenditure requirements and ATXI’s transmission projects, see Business under Part I, Item 1, of this report. We continually review Ameren Missouri’s 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 things. Additionally, we continually review the reliability of our transmission and distribution systems, expected capacity needs, and opportunities for transmission investments. 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, among other things. Any changes in future generation, transmission, or distribution needs could result in significant capital expenditures or losses being incurred, which could be material. Environmental Capital Expenditures Ameren Missouri will incur significant costs in future years to comply with existing and known federal and state regulations including those requiring the reduction of SO2, NOx, and mercury emissions from its coal-fired energy centers. 53 See Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for a discussion of existing environmental laws and regulations that affect, or may affect, our facilities and capital costs to comply with such laws and regulations. Cash Flows from Financing Activities 2013 versus 2012 In 2013, we reduced our cost of borrowings through the repayment and redemption of long-term indebtedness, which had higher interest rates than the commercial paper and senior secured debt issued to finance such repayments and redemptions. During 2013, issuances under the Ameren and Ameren Missouri commercial paper programs were available at a lower interest rate than the interest rate available under the 2012 Credit Agreements. Ameren’s net cash used in financing activities associated with continuing operations decreased during 2013 compared with 2012. In 2013, Ameren’s cash flow from operating activities of $1.6 billion exceeded its capital expenditures of $1.4 billion while in 2012 Ameren’s cash flow from operating activities of $1.4 billion exceeded its capital expenditures of $1.1 billion. During 2013, Ameren used cash flow from operating activities, other available cash on hand, and commercial paper issuances in part, to pay common stock dividends of $388 million, redeem $244 million of long-term Ameren Missouri indebtedness, and fund the $235 million cash requirement at divested New AER upon divestiture on December 2, 2013, pursuant to the transaction agreement with IPH. In addition, Ameren Illinois issued $280 million in senior secured debt and used the net proceeds of $276 million to repay at maturity $150 million of long-term indebtedness. In comparison, in 2012, Ameren subsidiaries issued $885 million in senior debt and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $754 million and pay related premiums. Additionally, in 2012, Ameren repaid $148 million of its net short-term debt. During 2013, no financing cash flows were utilized to meet the working capital and investing requirements of our discontinued operations. Ameren Missouri’s net cash used in financing activities increased during 2013, compared with 2012. Ameren Missouri used cash on hand, net money pool receipts, and the excess cash from operating activities after capital expenditures, to redeem or repay existing long-term indebtedness of $244 million and pay common stock dividends of $460 million. In comparison, in 2012, Ameren Missouri issued $485 million of 3.90% senior secured notes and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $422 million and to pay related premiums. Ameren Illinois’ financing activities provided net cash of $45 million in 2013 compared with 2012, when financing activities used net cash of $103 million. During 2013, Ameren Illinois issued $280 million in senior secured debt and used the net proceeds of $276 million to repay at maturity $150 million of long-term indebtedness, and pay common stock dividends of $110 million. During 2012, Ameren Illinois issued $400 million of 2.70% senior secured notes and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $332 million and to pay related premiums. Ameren Illinois paid common stock dividends of $189 million in 2012. 2012 versus 2011 During 2012, we replaced and extended our credit agreements. We reduced our reliance on short-term debt while maintaining adequate cash balances for working capital needs. Ameren’s net cash used in financing activities associated with continuing operations decreased during 2012, compared with 2011. Repayments of net short-term debt and credit agreement borrowings decreased by $333 million in 2012 compared with 2011. The decrease in cash provided by operating activities in 2012, combined with the increase in capital expenditures, resulted in less cash available to fund financing activities. However, Ameren was still able to repay all outstanding short-term debt that existed at the end of 2011. In 2012, Ameren subsidiaries issued $885 million in senior debt and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $754 million and to pay related premiums. In 2011, Ameren Illinois funded the $150 million maturity of its senior secured notes with cash on hand and operating cash flows. There was also a reduction in refunds of advances previously received from generators of $73 million due to project completion in 2011. In 2011, common stock issued for DRPlus and the 401(k) plan increased cash flows from financing activities by $65 million. In 2012, Ameren shares were purchased in the open market for DRPlus and the 401(k) plan, resulting in noncash financing activity of $7 million due to the timing of DRPlus common stock dividend funding. During 2012, no financing cash flows were utilized to meet working capital and investing requirements associated with discontinued operations. In 2011, $100 million of short-term borrowing obligations were repaid using surplus net cash from operating activities. Ameren Missouri’s net cash used in financing activities decreased during 2012, compared with 2011. In September 2012, Ameren Missouri issued $485 million of 3.90% senior secured notes and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $422 million and to pay related premiums. In 2011, refunds of advances previously received from generators decreased cash flows from financing activities by $19 million as a result of project completion. Ameren Illinois’ net cash used in financing activities decreased during 2012, compared with 2011. In August 2012, Ameren Illinois issued $400 million of 2.70% senior secured notes and used the proceeds, together with other available cash, to redeem or repay existing long-term indebtedness of $332 million and pay related premiums. In 2011, Ameren Illinois funded the $150 million maturity of its senior secured notes by using cash on hand and operating cash flows. In 2012, Ameren Illinois common stock dividends decreased by $138 million relative to 2011 dividends. Additionally, there was a reduction in 2012 in refunds of advances previously received from generators of $53 million due to project completion in 2011. Credit Facility Borrowings and Liquidity The liquidity needs of Ameren, Ameren Missouri and Ameren Illinois are typically supported through the use of available cash, short-term intercompany borrowings, drawings under committed bank credit agreements, or, for Ameren and Ameren Missouri, commercial paper issuances. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for additional information on credit agreements, short-term borrowing activity, commercial paper issuances, relevant interest rates, and borrowings under Ameren’s money pool arrangements. The following table presents the committed 2012 Credit Agreements of Ameren, Ameren Missouri, and Ameren Illinois, and the credit capacity available under such agreements, considering reductions for commercial paper issuances and letters of credit, as of December 31, 2013: Expiration Borrowing Capacity Credit Available Ameren and Ameren Missouri: 2012 Missouri Credit Agreement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . November 2017 $ 1,000 $ 1,000 Ameren and Ameren Illinois: 2012 Illinois Credit Agreement(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . November 2017 1,100 Ameren: Less: Commercial paper outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Letters of credit(b) (c) (c) 1,100 (368) (14) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2,100 $ 1,718 (a) The borrowing sublimit of Ameren Illinois will mature and expire on September 30, 2014, subject to extension on a 364-day basis, or for a longer period upon notice by Ameren Illinois of receipt of any and all required federal or state regulatory approvals, as permitted under the 2012 Illinois Credit Agreement, but in no event later than November 14, 2017. In October 2013, Ameren Illinois filed a petition seeking state regulatory approval necessary to extend the maturity date of its borrowing sublimit under the 2012 Illinois Credit Agreement to November 14, 2017. (b) As of December 31, 2013, $11 million of the letters of credit relate to Ameren’s ongoing credit support obligations to New AER. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information. (c) Not applicable. 54 The 2012 Credit Agreements are used to borrow cash, to issue letters of credit, and to support issuances under Ameren’s and Ameren Missouri’s commercial paper programs. Either of the 2012 Credit Agreements are available to Ameren to support issuances under Ameren’s commercial paper program, subject to borrowing sublimits. The 2012 Missouri Credit Agreement is available to support issuances under Ameren Missouri’s commercial paper program. Ameren Illinois’ commercial paper program, under which no commercial paper was ever issued, was terminated in 2013. During 2013, issuances under the Ameren and Ameren Missouri commercial paper programs were available at a lower interest rate than the interest rate available under the 2012 Credit Agreements. As such, commercial paper issuances were a preferred source of third-party short-term debt relative to credit facility borrowings. The maximum aggregate amount available to each borrower under each facility is shown in the following table (such amount being such borrower’s “Borrowing Sublimit”): 2012 Missouri Credit Agreement 2012 Illinois Credit Agreement Ameren . . . . . . . . . . . . . . . . . . . . . Ameren Missouri Ameren Illinois . . . . . . . . . $ 500 800 (a) $ 300 (a) 800 (a) Not applicable. Subject to applicable regulatory short-term borrowing authorizations, these credit arrangements are also available to Ameren’s non-state-regulated subsidiaries through direct short-term borrowings from Ameren and to most of Ameren’s non-rate-regulated subsidiaries, including, but not limited to, Ameren Services, through a money pool agreement. Ameren has money pool agreements with and among its subsidiaries to coordinate and to provide for certain short-term cash and working capital requirements. Long-term Debt and Equity In addition, a unilateral borrowing agreement among Ameren, Ameren Illinois, and Ameren Services enables Ameren Illinois to make short-term borrowings directly from Ameren. Pursuant to the terms of the unilateral borrowing agreement, the aggregate amount of borrowings outstanding at any time by Ameren Illinois under the unilateral borrowing agreement and the money pool agreement, together with any outstanding Ameren Illinois external credit facility borrowings or commercial paper issuances, may not exceed $500 million, pursuant to the authorization from the ICC. Ameren Illinois did not borrow under the unilateral borrowing agreement during 2013 or 2012. Ameren Services is responsible for operation and administration of the money pool agreements. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for a detailed explanation of the money pool arrangements and the unilateral borrowing agreement. The issuance of short-term debt securities by Ameren’s utility subsidiaries is subject to approval by FERC under the Federal Power Act. In February 2014, FERC issued an order effective March 17, 2014, authorizing the issuance of up to $1 billion of short-term debt securities for Ameren Missouri. The authorization terminates on March 16, 2016. In September 2012, FERC issued an order authorizing the issuance of up to $1 billion of short-term debt securities by Ameren Illinois. The authorization terminates on September 30, 2014. Ameren Illinois will file for a two-year extension of the FERC short-term borrowing authorization in 2014. The issuance of short-term debt securities by Ameren is not subject to approval by any regulatory body. The Ameren Companies continually evaluate the adequacy and appropriateness of their liquidity arrangements given changing business conditions. When business conditions warrant, changes may be made to existing credit agreements or to other short-term borrowing arrangements. The following table presents the issuances of common stock and the issuances, redemptions, repurchases, and maturities of long-term debt (net of any issuance discounts) for the years 2013, 2012, and 2011 for the Ameren Companies. The Ameren Companies did not have any redemptions and repurchases of preferred stock during the years 2013, 2012, and 2011. For additional information related to the terms and uses of these issuances and the sources of funds and terms for the redemptions, see Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report. Month Issued, Redeemed, Repurchased, or Matured 2013 2012 2011 Issuances Long-term debt Ameren Missouri: 3.90% Senior secured notes due 2042 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September Ameren Illinois: 2.70% Senior secured notes due 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.80% Senior secured notes due 2043 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . August December Total Ameren long-term debt issuances . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Common stock Ameren: DRPlus and 401(k) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Various Total common stock issuances . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren long-term debt and common stock issuances . . . . . . . . . . . . . . $ $ $ $ $ - $ 482 $ - 278 278 - - 278 $ $ $ $ 400 - 882 $ - $ - $ 882 $ - - - - 65 65 65 55 Redemptions, Repurchases and Maturities Long-term debt Ameren Missouri: City of Bowling Green capital lease (Peno Creek CT) . . . . . . . . . . . . . . . . . . 5.25% Senior secured notes due 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.00% Senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.70% Senior secured notes due 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.10% Senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.10% Senior secured notes due 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 5.45% Series pollution control revenue bonds due 2028 . . . . . . . . . . 4.65% Senior secured notes due 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: 6.625% Senior secured notes due 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.75% Senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.25% Senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2000 Series A 5.50% pollution control revenue bonds due 2014 . . . . . . . . . 6.20% Series 1992B due 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.875% Senior secured notes due 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren long-term debt redemptions, repurchases and maturities . . . . . . In October 2013, 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 sold 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. Ameren filed a Form S-3 registration statement with the SEC in June 2011, authorizing the offering of 6 million additional shares of its common stock under DRPlus. Shares of common stock sold under DRPlus are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. In 2013 and 2012, Ameren shares were purchased in the open market for DRPlus and its 401(k) plan. Under DRPlus and its 401(k) plan, Ameren issued 2.2 million shares of common stock in 2011, which were valued at $65 million. In June 2012, Ameren, Ameren Missouri and Ameren Illinois filed a Form S-3 shelf registration statement registering the issuance of an indeterminate amount of certain types of securities, which expires in June 2015. 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. Indebtedness Provisions and Other Covenants 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 bank credit agreements and in certain of the Ameren Companies’ indentures and articles of incorporation. 56 Month Issued, Redeemed, Repurchased, or Matured 2013 2012 2011 Various September September September September September October October June August August August November December $ $ 5 - - - - - 44 200 - - - - - 150 399 $ $ 5 173 71 121 1 56 - - - 87 194 51 1 - 760 $ $ 5 - - - - - - - 150 - - - - - 155 At December 31, 2013, the Ameren Companies were in compliance with the provisions and covenants contained within their credit agreements, indentures, and articles of incorporation. We consider access to short-term and long-term capital markets a significant source of funding for capital requirements not satisfied by our operating cash flows. 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. 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 $388 million, or $1.60 per share, in 2013, $382 million, or $1.60 per share, in 2012, and $375 million, or $1.555 per share, in 2011. The amount and timing of dividends payable on Ameren’s common stock are within the sole discretion of Ameren’s board of directors. The board of directors has not set specific targets or payout parameters when declaring common stock dividends. As in the past, the board of directors is expected to consider various issues, 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 14, 2014, the board of directors of Ameren declared a quarterly dividend on Ameren’s common stock of 40 cents per share, payable on March 31, 2014, to shareholders of record on March 12, 2014. 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 related to certain operating expenses and accumulations of earned surplus. 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.” 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 may not pay any dividend on its stock unless, among other things, its earnings and earned surplus are sufficient to declare and pay a dividend after provision is made for reasonable and proper reserves, or unless Ameren Illinois has specific authorization from the ICC. Ameren has committed to FERC to maintain a minimum of 30% equity in its capital structure at Ameren Illinois. At December 31, 2013, Ameren, Ameren Missouri and Ameren Illinois were not restricted from paying dividends. At December 31, 2013, the amount of restricted net assets of wholly owned subsidiaries of Ameren that may not be distributed to Ameren in the form of a loan or dividend was $2 billion. The following table presents common stock dividends paid by Ameren Corporation to its common shareholders and by Ameren’s registrant subsidiaries to Ameren. Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Dividends paid by Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 460 110 388 $ 400 189 382 $ 403 327 375 2013 2012 2011 Certain of the Ameren Companies have issued preferred stock, which provides for cumulative preferred stock dividends. Each company’s board of directors considers the declaration of the 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. 57 Contractual Obligations The following table presents our contractual obligations as of December 31, 2013. See Note 11 – Retirement Benefits under Part II, Item 8, of this report for information regarding expected minimum funding levels for our pension plans. These expected pension funding amounts are not included in the table below. In addition, routine short-term purchase order commitments are not included. Total Less than 1 Year 1 - 3 Years 3 - 5 Years After 5 Years Ameren:(a) Long-term debt and capital lease obligations(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest payments(d) Operating leases(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other obligations(f) $ 6,048 3,673 117 6,349 $ 534 331 14 1,519 $ 515 605 26 2,188 $ 1,521 496 26 1,201 $ 3,478 2,241 51 1,441 Total cash contractual obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 16,187 $ 2,398 $ 3,334 $ 3,244 $ 7,211 Ameren Missouri: Long-term debt and capital lease obligations(c) . . . . . . . . . . . . . . . . . . . . . . . . . Interest payments(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating leases(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other obligations(f) $ $ 3,764 2,574 106 4,308 109 211 11 895 $ 386 395 22 1,688 $ 814 325 23 1,030 $ 2,455 1,643 50 695 Total cash contractual obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 10,752 $ 1,226 $ 2,491 $ 2,192 $ 4,843 Ameren Illinois: Long-term debt(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest payments(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating leases(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other obligations(f) $ $ 1,859 1,086 7 1,960 Total cash contractual obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 4,912 $ - 107 2 573 682 $ $ 129 210 2 470 811 $ 707 171 2 171 $ 1,023 598 1 746 $ 1,051 $ 2,368 Includes amounts for registrant and nonregistrant Ameren subsidiaries and intercompany eliminations. (a) (b) Excludes fair-market value adjustments of Ameren Illinois’ long-term debt of $4 million. (c) Excludes unamortized discount and premium of $14 million at Ameren, $7 million at Ameren Missouri and $7 million at Ameren Illinois. (d) The weighted-average variable-rate debt has been calculated using the interest rate as of December 31, 2013. (e) Amounts for certain land-related leases have indefinite payment periods. The annual obligation of $2 million, $1 million, and $1 million for Ameren, Ameren Missouri and Ameren Illinois, respectively, for these items is included in the Less than 1 Year, 1 – 3 Years, and 3 – 5 Years columns. (f) See Other Obligations in Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for discussion of items included herein. As of December 31, 2013, the amounts of Off-Balance-Sheet Arrangements unrecognized tax benefits (detriments) under the authoritative accounting guidance for uncertain tax positions were $90 million, $31 million, and $(1) million for Ameren, Ameren Missouri, and Ameren Illinois, respectively. It is reasonably possible to expect that the settlement of an unrecognized tax benefit will result in an underpayment or overpayment of tax and related interest. However, there is a high degree of uncertainty with respect to the timing of cash payments or receipts associated with unrecognized tax benefits. The amount and timing of certain payments or receipts is not reliably estimable or determinable at this time. See Note 13 – Income Taxes under Part II, Item 8, of this report for information regarding the Ameren Companies’ unrecognized tax benefits and related liabilities for interest expense. At December 31, 2013, none of the Ameren Companies had off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business. None of the Ameren Companies expect to engage in any significant off-balance-sheet financing arrangements in the near future. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for Ameren (parent) guarantees and letters of credit issued to support New AER based on the transaction agreement with IPH. Credit Ratings The credit ratings of the Ameren Companies affect our liquidity, our access to the capital markets and credit markets, our cost of borrowing under our credit facilities, and collateral posting requirements under commodity contracts. 58 The following table presents the principal credit ratings of the Ameren Companies by Moody’s, S&P, and Fitch effective on the date of this report: Ameren: Issuer/corporate credit rating . . . . . . . . Senior unsecured debt . . . . . . . . . . . . . Commercial paper . . . . . . . . . . . . . . . . . Ameren Missouri: Issuer/corporate credit rating . . . . . . . . Secured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt Ameren Illinois: Issuer/corporate credit rating . . . . . . . . Secured debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Senior unsecured debt Moody’s S&P Fitch Baa2 Baa2 P-2 Baa1 A2 Baa1 Baa1 A2 Baa1 BBB+ BBB A-2 BBB+ A BBB+ BBB+ A BBB+ BBB BBB F2 BBB+ A A- BBB- BBB+ BBB The cost of borrowing under our credit facilities can also increase or decrease depending upon the credit ratings of the borrower. 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 adverse change in the Ameren Companies’ 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 a potential negative impact on earnings. Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts at December 31, 2013, were $30 million, $15 million, and $15 million at Ameren, Ameren Missouri and Ameren Illinois, respectively. Cash collateral posted by external counterparties with Ameren and Ameren Illinois was $2 million and $2 million, respectively, at December 31, 2013. Sub-investment-grade issuer or senior unsecured debt ratings (lower than “BBB-” or “Baa3”) at December 31, 2013, 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 $122 million, $67 million, and $55 million, respectively. Changes in commodity prices could trigger additional collateral postings and prepayments at current credit ratings. If market prices were 15% higher than December 31, 2013, levels in the next 12 months and 20% higher thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, or Ameren Illinois could be required to post additional collateral or other assurances for certain trade obligations up to $1 million, $1 million, and $- million, respectively. If market prices were 15% lower than December 31, 2013, levels in the next 12 months and 20% lower thereafter through the end of the term of the commodity contracts, then Ameren, Ameren Missouri, or Ameren Illinois could be required to post additional collateral or other assurances for certain trade obligations up to $17 million, $2 million, and $15 million, respectively. The transaction agreement between Ameren and IPH required Ameren to maintain its financial obligations with respect to all credit support provided to New AER for all transactions entered into prior to the closing of the divestiture on December 2, 2013, for up to 24 months after the closing. The permitted forms of credit support for each counterparty agreement could include one or more of the following: cash, a letter of credit, a guarantee, or other credit support alternatives. Ameren’s exposure related to the continuation of credit support provided to New AER after December 2, 2013, depends upon the transactions and counterparty agreements that AER and its subsidiaries had in effect as of December 2, 2013, and any changes in the market prices of these transactions that require an increase or decrease in collateral postings. IPH shall indemnify Ameren for any payments Ameren makes pursuant to these credit support obligations if the counterparty does not return the posted collateral to Ameren. IPH’s indemnification obligation is secured by certain AERG and Genco assets. In addition, Dynegy has provided a limited guarantee of $25 million to Ameren (parent) pursuant to which Dynegy will, among other things, guarantee IPH’s indemnification obligations for a period of up to 24 months after the closing (subject to certain exceptions). As of December 31, 2013, Ameren provided $190 million in guarantees and letters of credit totaling $11 million relating to its credit support of New AER. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information regarding Ameren (parent) guarantees and Ameren’s transaction agreement divesting New AER to IPH. Immediately prior to the transaction agreement closing on December 2, 2013, the cash collateral provided to New AER by Ameren through money pool borrowings was converted to a note payable to Ameren, which is payable, with interest, 24 months after closing or sooner as cash collateral requirements are reduced. The balance of the note was $18 million at December 31, 2013; it will vary over the 24-month period as cash collateral requirements for New AER change. Changes in commodity prices could trigger additional collateral postings and prepayments for New AER and thus affect the balance of the note. If market prices were 15% higher than December 31, 2013, levels in the next 12 months and 20% higher thereafter through the end of the term of the commodity contracts, then Ameren could be required to provide additional credit support to IPH up to $105 million. If market prices were 15% lower than December 31, 2013, levels in the next 12 months and 20% lower thereafter through the end of the term of the commodity contracts, then Ameren could be required to provide IPH with additional credit support up to $43 million. OUTLOOK Ameren seeks to earn competitive returns on its investments in its businesses. Ameren Missouri and Ameren Illinois are seeking to improve their regulatory 59 frameworks and cost recovery mechanisms and simultaneously pursuing constructive regulatory outcomes within existing frameworks. Ameren Missouri and Ameren Illinois are seeking to align their overall spending, both operating and capital, with economic conditions and cash flows provided by their regulators. Consequently, Ameren’s rate-regulated businesses are focused on minimizing the gap between allowed and earned returns on equity. Ameren intends to allocate its capital resources to those business opportunities that offer the most attractive risk-adjusted return potential. Below are some key trends, events, and uncertainties that are reasonably likely to affect the Ameren Companies’ results of operations, financial condition, or liquidity, as well as their ability to achieve strategic and financial objectives, for 2014 and beyond. Operations ‰ ‰ ‰ Ameren’s strategy for earning competitive returns on its rate-regulated investments involves meeting customer energy needs in an efficient fashion, working to enhance regulatory frameworks, making timely and well-supported rate case filings, and aligning overall spending with those rate case outcomes, economic conditions, and return opportunities. Ameren continues to pursue its plans to invest in FERC- regulated electric transmission. MISO has approved three electric transmission projects to be developed by ATXI. The first project, Illinois Rivers, involves the construction of a 345-kilovolt line from western Indiana across the state of Illinois to eastern Missouri. ATXI obtained a certificate of public convenience and necessity and project approval from the ICC for the entire Illinois Rivers project. A full range of construction activities is scheduled in 2014. The first sections of the Illinois Rivers project are expected to be completed in 2016. The last section of this project is expected to be completed in 2019. The Spoon River project in northwest Illinois and the Mark Twain project in northeast Missouri are the other two projects approved by MISO. These two projects are expected to be completed in 2018. The total investment in these three projects is expected to be $1.4 billion through 2019. Separate from the ATXI projects discussed above, Ameren Illinois expects to invest approximately $850 million in electric transmission assets over the next five years to address load growth and reliability requirements. In July 2013, Illinois enacted the Natural Gas Consumer, Safety and Reliability Act, which encourages Illinois natural gas utilities to accelerate modernization of the state’s natural gas infrastructure and provides additional ICC oversight of natural gas utility performance. The law allows natural gas utilities the option to file for, and requires the ICC to approve, a rate rider mechanism to recover costs of certain natural gas infrastructure investments made between rate cases. The law does not require a minimum level of investment. Ameren Illinois expects to begin including ‰ ‰ ‰ ‰ investments under this regulatory framework in 2015. Ameren Illinois’ decision to accelerate modernization of its natural gas infrastructure under this regulatory framework is dependent upon multiple considerations, including the allowed return on equity under this framework compared with other Ameren and Ameren Illinois investment options. The IEIMA provides for an annual reconciliation of the revenue requirement necessary to reflect the actual costs incurred in a given year with the revenue requirement that was in effect for customer billings for that year. Consequently, Ameren Illinois’ 2014 electric delivery service revenues will be based on its 2014 actual recoverable costs, rate base, and return on common equity as calculated under the IEIMA’s performance-based formula ratemaking framework. The 2014 revenue requirement is expected to be higher than the 2013 revenue requirement, due to an expected increase in recoverable costs, rate base growth, and expected increase in the monthly average of United States treasury bonds. In December 2013, the ICC issued an order with respect to Ameren Illinois’ annual update IEIMA filing. The ICC approved a net $45 million decrease in Ameren Illinois’ electric delivery service rates, which represents an annual revenue requirement increase of $23 million primarily due to higher recoverable costs in 2012 compared to 2011, offset by a $68 million refund to customers relating to the 2012 revenue requirement reconciliation. The ICC decision issued in December 2013 established new rates that became effective January 1, 2014. These rates will affect Ameren Illinois’ cash flows during 2014, but not its operating revenues, which will instead be determined by the IEIMA’s 2014 revenue requirement reconciliation. The 2014 revenue requirement reconciliation will be reflected as a regulatory asset or liability that will be collected from or refunded to customers in 2016. In December 2013, the ICC issued an order that authorized a $32 million increase in Ameren Illinois’ annual natural gas delivery service revenues. This request was based on a future test year of 2014, which improves the ability to earn returns allowed by regulators. The new rates became effective January 1, 2014. On February 13, 2014, Ameren Missouri’s largest customer, Noranda, and 37 residential customers filed an earnings complaint case and a rate design complaint case with the MoPSC. In the earnings complaint case, Noranda and the residential customers asserted that Ameren Missouri’s electric delivery service business is earning more than the 9.8% return on equity authorized in the MoPSC’s December 2012 electric rate order and requested the MoPSC to approve a reduction of the authorized return on equity to 9.4%. The rate design complaint case seeks to reduce Noranda’s electricity cost with an offsetting increase in electricity cost for Ameren Missouri’s other customers. The rate design complaint case asks the MoPSC to expedite its decision and grant relief by August 1, 2014. The MoPSC has no 60 time requirement by which it must issue an order in these cases. Ameren Missouri opposes both requests filed by Noranda and the residential customers and will vigorously defend itself. As we continue to experience cost increases and make infrastructure investments, Ameren Missouri and Ameren Illinois expect to seek regular electric and natural gas rate increases and timely cost recovery and tracking mechanisms from their regulators. Ameren Missouri expects to file an electric service rate case in July 2014. Ameren Missouri and Ameren Illinois will also seek, as necessary, legislative solutions to address cost recovery pressures and to support investment in their energy infrastructure. These pressures include a weak economy, customer conservation efforts, the impacts of energy efficiency programs, increased investments and expected future investments for environmental compliance, system reliability improvements, and new generation capacity, including renewable energy requirements. Increased investments also result in higher depreciation and financing costs. Increased costs are also expected from rising employee benefit costs, higher property and income taxes, and higher insurance premiums as a result of insurance market conditions and industry loss experience, among other things. Ameren and Ameren Missouri also are pursuing recovery from insurers, through litigation, for reimbursement of unpaid liability insurance claims for a December 2005 breach of the upper reservoir at Ameren Missouri’s Taum Sauk pumped-storage hydroelectric energy center. Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity could be adversely affected if Ameren Missouri’s remaining liability insurance claims of $68 million as of December 31, 2013, are not paid by insurers. Ameren Missouri’s next scheduled refueling and maintenance outage at its Callaway energy center will be in the fall of 2014. During a scheduled outage, which occurs every 18 months, maintenance expenses increase relative to non-outage years. Additionally, 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, resulting in limited impacts to earnings. Electric operating revenues in 2013 did not fully offset the additional maintenance costs incurred during the 2013 outage, because revenues relating to the additional maintenance costs are recovered over 18 months. Ameren Missouri continues to evaluate its longer-term needs for new baseload and peaking electric generation capacity. As of December 31, 2013, Ameren Missouri had capitalized $69 million of costs incurred to license additional nuclear generation at its Callaway energy site. If efforts are abandoned or management ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ concludes it is probable the costs incurred will be disallowed in rates, a charge to earnings would be recognized in the period in which that determination was made. Environmental regulations, as well as future initiatives, including those related to greenhouse gas emissions, could result in significant increases in capital expenditures and operating costs. These expenses could be prohibitive at some of Ameren Missouri’s coal-fired energy centers, particularly at its Meramec energy center. Ameren Missouri’s capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances as well as prolonged periods before recovery of these investments occur. Both Ameren Illinois and ATXI have FERC authorization to employ a forward-looking rate calculation with an annual revenue requirement reconciliation for each company’s electric transmission business. With the projected rates that became effective on January 1, 2014, Ameren Illinois’ 2014 revenue requirement for its electric transmission business is expected to increase by $15 million over 2013 levels due to rate base growth. With the projected rates that became effective on January 1, 2014, ATXI’s 2014 revenue requirement for its electric transmission business is expected to increase by $21 million over 2013 levels due to rate base growth, primarily relating to the Illinois Rivers project. In November 2013, a customer group filed a complaint case with FERC seeking a reduction in the allowed return on common equity, as well as a limit on the common equity ratio, under the MISO tariff. Currently, the FERC-allowed return on common equity for MISO transmission owners is 12.38%. This complaint case could result in a reduction to Ameren Illinois’ and ATXI’s allowed return on common equity. That reduction could also result in a refund for transmission service revenues earned after the filing of the complaint case in November 2013. FERC has not issued an order in this case, and it is under no deadline to do so. For additional information regarding recent rate orders and related appeals, pending requests filed with state and federal regulatory commissions, Taum Sauk matters, and separate FERC orders affecting Ameren Missouri and Ameren Illinois, see Note 2 – Rate and Regulatory Matters, Note 10 – Callaway Energy Center, and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report. Liquidity and Capital Resources ‰ The Ameren Companies seek to maintain access to the capital markets at commercially attractive rates in order to fund their businesses. The Ameren Companies seek to enhance regulatory frameworks and returns in order to improve cash flows, credit metrics, and related access to capital for Ameren’s rate-regulated businesses. The use of operating cash flows and short-term borrowings to fund capital expenditures and other long- term investments may periodically result in a working ‰ 61 ‰ ‰ ‰ capital deficit, as defined by current liabilities exceeding current assets, as was the case at December 31, 2013. The working capital deficit as of December 31, 2013, was primarily the result of current maturities of long- term debt. Ameren is currently evaluating refinancing options for these current maturities including, in part, through the issuance of long-term notes. In addition, Ameren had $368 million of commercial paper issuances outstanding as of December 31, 2013. With the 2012 Credit Agreements, Ameren has access to $2.1 billion of credit capacity of which $1.7 billion was available at December 31, 2013. In May 2014, $425 million of Ameren’s 8.875% senior unsecured notes and $104 million of Ameren Missouri’s 5.50% senior secured notes will mature. Ameren expects to refinance its parent company debt at a lower interest rate, which will reduce its interest expense. Ameren expects its cash used for capital expenditures and dividends to exceed cash provided by operating activities over the next few years. As of December 31, 2013, Ameren had $408 million in tax benefits from federal and state net operating loss carryforwards (Ameren Missouri – $64 million and Ameren Illinois – $95 million) and $118 million in federal and state income tax credit carryforwards (Ameren Missouri – $12 million and Ameren Illinois – none). Consistent with the tax allocation agreement between Ameren and its subsidiaries, these carryforwards are expected to partially offset income tax liabilities in 2014 for Ameren Missouri and for Ameren and Ameren Illinois into 2016. In addition, Ameren has $85 million of expected income tax refunds and state overpayments that will offset income tax liabilities into 2016. These tax benefits, primarily at the Ameren (parent) level, when realized, will be available to finance electric transmission investments, specifically ATXI’s Illinois Rivers project. These tax benefits are projected to reduce or eliminate Ameren’s need to issue additional equity to fund these investments over the next few years. ‰ ‰ In December 2011, the IRS issued new guidance on the treatment of amounts paid to acquire, produce, or improve tangible property and dispositions of such property with respect to electric transmission, distribution, and generation assets as well as natural gas transmission and distribution assets. Final regulations related to this guidance were issued in September 2013. Based on a preliminary evaluation of the new guidance, Ameren expects to use $40 million (Ameren Missouri – $24 million and Ameren Illinois – $16 million) in federal income tax net operating loss carryforward benefits to offset tax liabilities related to the accounting method change that Ameren expects to file with the IRS in 2014 in connection with this new guidance. In November 2012, the Ameren Companies entered into multiyear credit agreements that cumulatively provide $2.1 billion of credit through November 14, 2017. See Note 4 – Short-term Debt and Liquidity under Part II, Item 8, of this report for additional information regarding the 2012 Credit Agreements. Ameren, Ameren Missouri, and Ameren Illinois believe that their liquidity is adequate given their expected operating cash flows, capital expenditures, and related financing plans. 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. The above items could have a material impact on our results of operations, financial position, or liquidity. Additionally, in the ordinary course of business, we evaluate strategies to enhance our results of operations, financial position, or liquidity. These strategies may include acquisitions, divestitures, and opportunities to reduce costs or increase revenues, and other strategic initiatives to increase Ameren’s stockholder 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 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. 62 Accounting Estimate Uncertainties Affecting Application Regulatory Mechanisms and Cost Recovery The Ameren Companies defer costs in accordance with authoritative accounting guidance, and make investments that they assume will be collected in future rates. ‰ ‰ ‰ ‰ ‰ ‰ Regulatory environment and external regulatory decisions and requirements Anticipated future regulatory decisions and our assessment of their impact Impact of deregulation, rate freezes, prudency reviews, and opposition during the ratemaking process that may limit our ability to timely recover costs Ameren Illinois’ assessment of and ability to estimate the current year’s electric delivery service costs to be reflected in revenues and recovered from customers in a subsequent year under the IEIMA performance-based formula ratemaking process 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 process Estimate of revenue recovery from MEEIA Basis for Judgment We determine which costs are recoverable by reviewing previous rulings by regulatory authorities in jurisdictions where we operate and any other factors that may indicate whether cost recovery is probable. 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. Ameren Illinois estimates its annual revenue requirement pursuant to the IEIMA for interim periods by using internal forecasted information, such as projected operations and maintenance expenses, depreciation expense, taxes other than income taxes, and rate base, as well as published forecasted data regarding that year’s monthly average yields of the 30-year United States treasury bonds. 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 of or refund to customers that the ICC will order at the end of the following year. Variations in costs incurred, 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 electric transmission businesses. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for quantification of these assets for each of the Ameren Companies. Benefit Plan Accounting Based on actuarial calculations, we accrue costs of providing future employee benefits in accordance with authoritative accounting guidance regarding benefit plans. See Note 11 – Retirement Benefits under Part II, Item 8, of this report. ‰ ‰ ‰ ‰ ‰ ‰ ‰ ‰ Future rate of return on pension and other plan assets Valuation inputs and assumptions used in the fair value measurements of plan assets excluding those inputs that are readily observable Interest rates used in valuing benefit obligations Health care cost trend rates Timing of employee retirements and mortality assumptions Ability to recover certain benefit plan costs from our ratepayers Changing market conditions that may affect investment and interest rate environments Impacts of the health care reform legislation enacted in 2010 Basis for Judgment 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. See Note 11 – Retirement Benefits under Part II, Item 8, of this report for sensitivity of Ameren’s benefit plans to potential changes in these assumptions. 63 Accounting Estimate Uncertainties Affecting Application Accounting for Contingencies We make judgments and estimates in recording and disclosing 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 the amount of the loss can be reasonably estimated. A gain contingency is not recorded until realized or realizable. ‰ ‰ ‰ ‰ ‰ 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 each contingency in future periods. In making the determination as to the amount of potential loss and the probability of loss, we consider all available evidence including the expected outcome of potential litigation. 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. 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 10 – Callaway Energy Center, Note 15 – Commitments and Contingencies, and Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for information on the Ameren Companies’ contingencies. Accounting for Income Taxes Based on authoritative accounting guidance, we record the provision for income taxes, deferred tax assets and liabilities, and a valuation allowance against net deferred tax assets, if any. See Note 13 – Income Taxes under Part II, Item 8, of this report. ‰ ‰ ‰ ‰ ‰ ‰ 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 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 Results of audits and examinations of filed tax returns by taxing authorities Basis for Judgment The reporting of tax-related assets requires the use of estimates and significant management judgment. Deferred tax assets are recorded representing future effects on income taxes for temporary differences between the bases of assets for financial reporting and tax purposes. Although management believes that current estimates for deferred tax assets are reasonable, actual results could differ from these estimates for a variety of reasons including change in forecasted financial condition and/or results of operations, change in income tax laws or enacted tax rates, the form, structure, and timing of asset or stock sales or dispositions, and results of audits and examinations of filed tax returns 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 13 – Income Taxes under Part II, Item 8, of this report for the amount of deferred tax assets and uncertain tax positions recorded at December 31, 2013. 64 Accounting Estimate Unbilled Revenue At the end of each period, Ameren, Ameren Missouri, and Ameren Illinois project expected usage and estimate the amount of revenue to record for services that have been provided to customers but not yet billed. Uncertainties Affecting Application ‰ ‰ ‰ Projecting customer energy usage Estimating impacts of weather and other usage- affecting factors for the unbilled period Estimating loss of energy during transmission and delivery Basis for Judgment We base our estimate of unbilled revenue each period on the volume of energy delivered, as valued by a model of billing cycles and historical usage rates and growth or contraction by customer class for our service area. This figure is then adjusted for the modeled impact of seasonal and weather variations based on historical results. See the balance sheets for each of the Ameren Companies under Part II, Item 8, of this report for unbilled revenue amounts. Impact of Future Accounting Pronouncements See Note 1 – Summary of Significant Accounting Policies under Part II, Item 8, of this report. EFFECTS OF INFLATION AND CHANGING PRICES Ameren’s rates for retail electric and natural gas utility service are regulated by the MoPSC and the ICC. Nonretail electric rates are regulated by FERC. Rate regulation is generally based on the recovery of historical or projected costs. As a result, revenue increases could lag behind changing prices. Ameren Illinois elected to participate in the performance-based formula ratemaking process pursuant to the IEIMA for its electric delivery service business. Ameren Illinois’ participation in this formula ratemaking process will terminate if the average residential rate increases by more than 2.5% annually from June 2011 through May 2014. The average residential rate includes generation service, which is outside of Ameren Illinois’ control. Ameren Illinois is required to purchase all of its power through procurement processes administered by the IPA. The cost of procured power can be affected by inflation. Within the IEIMA formula, the monthly average yields of 30-year United States treasury bonds are the basis for Ameren Illinois’ return on equity. Therefore, there is a direct correlation between the yield of United States treasury bonds, which are affected by inflation, and the earnings of Ameren Illinois’ electric distribution business. Inflation affects our operations, earnings, stockholders’ equity, and financial performance. The current replacement cost of our utility plant substantially exceeds our recorded historical cost. Under existing regulatory practice, only the historical cost of plant is recoverable from customers. As a result, cash flows designed to provide recovery of historical costs through depreciation might not be adequate to replace plant in future years. Ameren Missouri recovers the cost of fuel for electric generation and the cost of purchased power by adjusting rates as allowed through the FAC. Ameren Illinois recovers power supply costs from electric customers by adjusting rates through a rider mechanism to accommodate changes in power prices. Ameren Missouri, Ameren Illinois and ATXI are affected by changes in the cost of electric transmission services. FERC regulates the rates charged and the terms and conditions for electric wholesale and unbundled retail transmission services. Because they are members of MISO, Ameren Missouri’s, Ameren Illinois’ and ATXI’s transmission rates are calculated in accordance with the rate formulas contained in MISO’s FERC-approved tariff. Under the MISO OATT, a portion of the revenue requirement related to certain projects eligible for cost sharing is allocated to multiple MISO pricing zones. The remaining revenue requirement is assigned to the pricing zone where the transmission assets are located. Ameren Missouri uses a rate formula that is updated in June of each year. It is based on the prior year’s cost data. The Ameren Missouri zonal rate is charged to wholesale customers in the AMMO pricing zone. This zonal rate is not directly charged to Missouri retail customers, because the MoPSC includes transmission-related costs in setting bundled retail rates in Missouri. Ameren Illinois and ATXI have received FERC approval to use company-specific, forward-looking rate formula templates in setting their transmission rates. These forward-looking rates are updated each January with forecasted information, with a subsequent reconciliation during the year to adjust for the actual revenue requirement and actual billed revenues, which will be used to adjust billing rates in a subsequent year. In Illinois, the AMIL pricing zone rate is charged directly to wholesale customers and alternative retail electric suppliers that serve unbundled retail load. For those Ameren Illinois retail customers that do not choose an alternative retail electric supplier, the AMIL transmission rate, as well as other MISO-related transmission costs, is collected through the retail transmission service rider mechanism. In our Missouri and Illinois retail natural gas utility jurisdictions, changes in natural gas costs are generally reflected in billings to natural gas customers through PGA clauses. See Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report for additional information on the cost recovery mechanisms. 65 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 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 Interest Rate Risk We are exposed to market risk through changes in interest rates associated with: ‰ ‰ ‰ ‰ long-term and short-term variable-rate debt; fixed-rate debt; auction-rate long-term debt; 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. The following table presents the estimated increase in our annual interest expense and decrease in net income if interest rates were to increase by 1% on variable-rate debt outstanding at December 31, 2013: Interest Expense Net Income(a) Ameren . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . $ 6 2 (b) $ (4) (1) (b) (a) Calculations are based on an estimated tax rate of 38%, 38% and 40% for Ameren, Ameren Missouri and Ameren Illinois, respectively. (b) Less than $1 million. 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 have 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, 2013. 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. Our rate-regulated 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, 2013, no nonaffiliated customer represented more than 10%, in the aggregate, of our accounts receivable. Additionally, Ameren Illinois has risk 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 is required to purchase the supplier’s receivables relating to Ameren Illinois’ delivery service 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 reflecting charges for electric delivery service and purchased receivables. As of December 31, 2013, Ameren Illinois’ balance of purchased accounts receivable associated with the utility consolidated billing and purchase of receivables services was $26 million. The risk associated with Ameren Illinois’ electric and natural gas trade receivables is also mitigated by a rate adjustment mechanism 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 increasing rates on customer collections. Ameren Missouri and Ameren Illinois make adjustments to their respective allowance for doubtful accounts as deemed necessary to ensure that such allowances are adequate to cover estimated uncollectible customer account balances. Ameren, Ameren Missouri and Ameren Illinois may have credit exposure associated with off-system or wholesale purchase and sale activity with nonaffiliated companies. At December 31, 2013, Ameren’s and Ameren Missouri’s combined credit exposure to nonaffiliated trading counterparties deemed below investment grade either through external or internal credit evaluations, net of collateral, was less than $1 million (2012 – $2 million). 66 We establish credit limits for these counterparties and monitor the appropriateness of these limits on an ongoing basis through a credit risk management program. Monitoring involves daily exposure reporting to senior management, master trading and netting agreements, and credit support, such as letters of credit and parental guarantees. We also analyze each counterparty’s financial condition before we enter into sales, forwards, swaps, futures, or option contracts. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. The transaction agreement between Ameren and IPH requires Ameren, for up to 24 months after the closing of the divestiture of New AER, to maintain its financial obligations in existence as of the date of the closing under all credit support arrangements or obligations with respect to New AER and its subsidiaries. Ameren must also provide any additional credit support that may be contractually required pursuant to any of the contracts of New AER, and its subsidiaries as of the closing. IPH, New AER and its subsidiaries and Dynegy have agreed to indemnify Ameren for certain losses relating to this credit support. IPH’s indemnification obligations are secured by certain AERG and Genco assets. However, these indemnification obligations and security interests might not cover all losses incurred by Ameren in connection with this credit support. In addition, Dynegy emerged from its Chapter 11 bankruptcy case on October 1, 2012, and, as of December 31, 2013, Dynegy’s credit ratings were sub- investment grade. IPH, New AER and its subsidiaries also do not have investment grade credit ratings. Dynegy, IPH, New AER, or their subsidiaries might not be able to pay their indemnity and other obligations under the transaction agreement, Marketing Company’s note to Ameren, or Dynegy’s limited guarantee to Ameren, which could have a material adverse impact on Ameren’s results of operations, financial position, and liquidity. As of December 31, 2013, the balance of the Marketing Company note to Ameren was $18 million. As of December 31, 2013, Ameren provided $190 million in guarantees and letters of credit totaling $11 million relating to its credit support of New AER. Equity Price Risk 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 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. In future years, the costs of such plans will be reflected in net income, or regulatory assets. Contributions to the plans could increase materially if we do not achieve pension and postretirement asset portfolio investment returns equal to or in excess of our 2014 assumed return on plan assets of 7.25% and 7.00%, respectively. 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, 2013, this fund was invested in domestic equity securities (68%) and debt securities (32%). As of December 31, 2013, the trust fund totaled $494 million (2012 – $408 million). 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. However, the equity securities included in the portfolio are exposed to price fluctuations in equity markets. The debt securities are exposed to changes in interest rates. 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 assets of the trust 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 has company-owned life insurance contracts that are used to support Ameren’s deferred compensation plans. These life insurance contracts include equity and debt investments that are exposed to price fluctuations in equity markets and to changes in interest rates. Commodity Price Risk With regard to Ameren Missouri’s and Ameren Illinois’ electric and natural gas distribution businesses, exposure to changing market prices 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 regulated customers. The effects of price volatility cannot 67 be eliminated. However, procurement 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, through customer rates, 95% of changes in fuel, certain fuel additives, emission allowances, purchased power costs, transmission costs and revenues, and MISO costs and revenues, net of off-system sales revenues, greater or less than the amount set in base rates, without a traditional rate proceeding, subject to MoPSC prudency review. Ameren Missouri remains exposed to the remaining 5% of such changes. Even with the FAC, Ameren Missouri enters into derivative contracts to hedge prices of electricity, coal and coal transportation for its customers as discussed above. Ameren Missouri also attempts to mitigate financial risks through risk management programs and policies, which include forward-hedging programs, and the use of derivative financial instruments (primarily forward contracts, futures contracts, option contracts, and financial swap contracts). However, a portion of the generation capacity of Ameren Missouri is not contracted through physical or financial hedge arrangements and is therefore exposed to volatility in market prices. If power prices were to decrease by 1% on unhedged economic generation for 2014 through 2018, Ameren Missouri earnings would decrease by less than $1 million, based on an 36% effective tax rate. Ameren Illinois has a cost recovery mechanism for power purchased on behalf of its customers. Ameren Illinois does not generate earnings based on the resale of power but rather on the delivery of energy. Ameren Illinois primarily purchases power through MISO with additional procurement events administered by the IPA. The IPA has proposed and the ICC has approved multiple energy procurement events covering portions of years through 2017. By the end of 2013, approximately 768,000 retail customers, representing 72% of Ameren Illinois’ annual retail kilowatthour sales, had elected to purchase their electricity from an alternative retail electric supplier. The percentage of retail customers, especially residential customers, who elected to purchase power from a different provider than Ameren Illinois increased substantially over the last two years. For periods where existing power purchases through the IPA exceed the demand for customers taking power from Ameren Illinois, the IPA has proposed, and the ICC has approved, that excess purchases will settle in the MISO market, thus resulting in a credit to customers who take supply from Ameren Illinois fixed-price tariffs. Ameren Illinois expects full recovery of its purchased power costs. 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 rate proceeding, subject to prudency review. The following table presents, as of December 31, 2013, 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 CTs and retail distribution, as appropriate, and purchased power for Ameren Illinois, which does not own generation, that are price-hedged over the period 2014 through 2018. The projected required supply of these commodities could be significantly affected by changes in our assumptions about customer demand for our electric generation and our electric and natural gas distribution services, generation output, and inventory levels, among other matters. 2014 2015 2016 – 2018 Ameren(a): . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Coal Coal transportation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear fuel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for distribution(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power for Ameren Illinois(c) Ameren Missouri: Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Coal transportation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Nuclear fuel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for generation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for distribution(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas for distribution(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased power(c) 100% 100 100 27 78 100 100% 100 100 27 84 77% 100 100% 100 100 22 27 85 100% 100 100 22 29 26% 85 70% 65 66 3 7 20 70% 65 66 3 18 5% 20 Includes intercompany eliminations. (a) (b) Represents the percentage of natural gas price-hedged for peak winter season of November through March. The year 2014 represents January 2014 through March 2014. The year 2015 represents November 2014 through March 2015. This continues each successive year through March 2018. (c) Represents the percentage of purchased power price-hedged for fixed-price residential and small commercial customers with less than one megawatt of demand. 68 With regard to our exposure for commodity price risk for construction and maintenance activities, Ameren is exposed to changes in market prices for metal commodities and to labor availability. See Transmission and Supply of Electric Power under Part I, Item 1, of this report for the percentages of our historical needs satisfied by coal, nuclear power, natural gas, hydroelectric power, and oil. Also see Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for additional information. Commodity Supplier Risk The use of ultra-low-sulfur coal is part of Ameren Missouri’s environmental compliance strategy. Ameren Missouri has a multiyear agreement to purchase ultra-low- sulfur coal through 2017 to comply with environmental regulations. The coal contract is with a single supplier. Disruptions of the deliveries of that ultra-low-sulfur coal from the supplier could compromise Ameren Missouri’s ability to operate in compliance with emission standards. Other sources of ultra-low-sulfur coal are limited, and the construction of pollution control equipment requires significant lead time if Ameren Missouri were to experience a temporary disruption of ultra-low-sulfur coal deliveries that caused it to exhaust its existing inventory, and if other sources of ultra-low-sulfur coal were not available, Ameren Missouri would use its existing emission allowances or purchase emission allowances to achieve compliance with environmental regulations. Currently, the Callaway energy center uses nuclear fuel assemblies of a design fabricated by only a single supplier. That supplier is currently the only NRC-licensed supplier able to provide assemblies to the Callaway energy center. If Ameren Missouri would decide to change suppliers or change the type of fuel assembly design the Callaway energy center uses, it could take up to 3 years of analysis and licensing effort to be in a position to use nuclear fuel assemblies fabricated from a different NRC-licensed nuclear fuel supplier. Fair Value of Contracts We use derivatives principally to manage the risk of changes in market prices for natural gas, diesel, power, and uranium. The following table presents the favorable (unfavorable) changes in the fair value of all derivative contracts marked-to-market during the year ended December 31, 2013. We use various methods to determine the fair value of our contracts. In accordance with authoritative accounting guidance for fair value hierarchy levels, the sources we used to determine the fair value of these contracts were active quotes (Level 1), inputs corroborated by market data (Level 2), and other modeling and valuation methods that are not corroborated by market data (Level 3). See Note 8 – Fair Value Measurements under Part II, Item 8, of this report for further information regarding the methods used to determine the fair value of these contracts. Fair value of contracts at beginning of year, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Contracts realized or otherwise settled during the period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Changes in fair values attributable to changes in valuation technique and assumptions . . . . . . . . . . . . . . . . . . . Fair value of new contracts entered into during the period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other changes in fair value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 3 (7) - 17 (4) (204) $ 84 - (4) (29) (201) 77 - 13 (33) Fair value of contracts outstanding at end of year, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 9 $ (153) $ (144) Ameren Missouri Ameren Illinois Ameren 69 The following table presents maturities of derivative contracts as of December 31, 2013, based on the hierarchy levels used to determine the fair value of the contracts: Sources of Fair Value Maturity Less Than 1 Year Maturity 1-3 Years Maturity 4-5 Years Maturity in Excess of 5 Years Total Fair Value Ameren Missouri: Level 1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 2(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 3(b) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Level 1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 2(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 3(b) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren: Level 1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 2(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Level 3(b) $ $ $ $ $ (2) $ (1) 18 $ $ 15 - (26) (9) $ - (4) - (4) $ $ - (19) (21) (35) $ (40) $ (2) $ (27) 9 $ - (23) (21) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (20) $ (44) $ - (1) - (1) - - (20) (20) - (1) (20) (21) $ $ $ $ $ $ - (1) - (1) - - (58) (58) - (1) (58) (59) $ $ $ $ $ $ (2) (7) 18 9 - (45) (108) (153) (2) (52) (90) (144) (a) Principally fixed-price vs. floating over-the-counter power swaps, power forwards, and fixed-price vs. floating over-the-counter natural gas swaps. (b) Principally power forward contract values based on information from external sources, historical results, and our estimates. Level 3 also includes option contract values based on a Black-Scholes model. ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Ameren Corporation: In our opinion, the consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Ameren Corporation and its subsidiaries at December 31, 2013 and 2012, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the index appearing under Item 15(a)(2) present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control – Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO 1992). The Company’s management is responsible for these financial statements and financial statement schedules, 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 these financial statements, on the financial statement schedules, and on the Company’s internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. 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. 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 70 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. /s/PricewaterhouseCoopers LLP PricewaterhouseCoopers LLP St. Louis, Missouri March 3, 2014 Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Union Electric Company: In our opinion, the financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Union Electric Company at December 31, 2013 and 2012, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the index appearing under Item 15(a)(2) presents fairly, in all material respects, the information set forth therein when read in conjunction with the related financial statements. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. /s/PricewaterhouseCoopers LLP PricewaterhouseCoopers LLP St. Louis, Missouri March 3, 2014 Report of Independent Registered Public Accounting Firm To the Board of Directors and Shareholders of Ameren Illinois Company: In our opinion, the financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Ameren Illinois Company at December 31, 2013 and 2012, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the index appearing under Item 15(a)(2) presents fairly, in all material respects, the information set forth therein when read in conjunction with the related financial statements. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. /s/PricewaterhouseCoopers LLP PricewaterhouseCoopers LLP St. Louis, Missouri March 3, 2014 71 AMEREN CORPORATION CONSOLIDATED STATEMENT OF INCOME (LOSS) (In millions, except per share amounts) Year Ended December 31, 2012 2013 2011 Operating Revenues: Electric Gas Total operating revenues Operating Expenses: Fuel Purchased power Gas purchased for resale Other operations and maintenance Taum Sauk regulatory disallowance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income and Expenses: Miscellaneous income Miscellaneous expense Total other income Interest Charges Income Before Income Taxes Income Taxes Income from Continuing Operations Income (Loss) from Discontinued Operations, Net of Taxes (Note 16) Net Income (Loss) Less: Net Income (Loss) Attributable to Noncontrolling Interests: Continuing Operations Discontinued Operations Net Income (Loss) Attributable to Ameren Corporation: Continuing Operations Discontinued Operations Net Income (Loss) Attributable to Ameren Corporation Earnings (Loss) per Common Share – Basic: Continuing Operations Discontinued Operations Earnings (Loss) per Common Share – Basic Earnings (Loss) per Common Share – Diluted: Continuing Operations Discontinued Operations Earnings (Loss) per Common Share – Diluted Dividends per Common Share Average Common Shares Outstanding – Basic Average Common Shares Outstanding – Diluted $ $ $ $ $ $ $ 4,832 1,006 5,838 845 502 526 1,617 - 706 458 4,654 1,184 69 26 43 398 829 311 518 (223) 295 6 - 512 (223) 289 2.11 (0.92) 1.19 2.10 (0.92) 1.18 1.600 242.6 244.5 $ $ $ $ $ $ $ 4,857 924 5,781 714 780 472 1,511 - 673 443 4,593 1,188 70 37 33 392 829 307 522 (1,496) (974) 6 (6) 516 (1,490) (974) 2.13 (6.14) (4.01) 2.13 (6.14) (4.01) 1.600 242.6 243.0 $ $ $ $ $ $ $ 5,147 1,001 6,148 866 952 570 1,562 89 643 433 5,115 1,033 68 23 45 387 691 254 437 89 526 6 1 431 88 519 1.79 0.36 2.15 1.79 0.36 2.15 1.555 241.5 242.1 The accompanying notes are an integral part of these consolidated financial statements. 72 AMEREN CORPORATION CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (LOSS) (In millions) Year Ended December 31, 2012 2013 2011 Income from Continuing Operations $ 518 $ 522 $ 437 Other Comprehensive Income (Loss), Net of Taxes: Pension and other postretirement benefit plan activity, net of income taxes (benefit) of $16, $(6), and $(14), respectively Comprehensive Income from Continuing Operations Less: Comprehensive Income from Continuing Operations Attributable to Noncontrolling Interests Comprehensive Income from Continuing Operations Attributable to Ameren Corporation Income (Loss) from Discontinued Operations, Net of Taxes Other Comprehensive Income (Loss) from Discontinued Operations, Net of Income Taxes (Benefit) of $(10), $40, and $(14), respectively 30 548 6 542 (223) (18) (8) 514 6 508 (1,496) (19) 418 6 412 89 58 (20) Comprehensive Income (Loss) from Discontinued Operations Less: Comprehensive Income from Discontinued Operations Attributable to Noncontrolling Interest Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Corporation (241) (1,438) 1 2 (242) (1,440) 69 (5) 74 Comprehensive Income (Loss) Attributable to Ameren Corporation $ 300 $ (932) $ 486 The accompanying notes are an integral part of these consolidated financial statements. 73 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 $18 and $17, respectively) Unbilled revenue Miscellaneous accounts and notes receivable Materials and supplies Current regulatory assets Current accumulated deferred income taxes, net Other current assets Assets of discontinued operations (Note 16) Total current assets Property and Plant, Net Investments and Other Assets: Nuclear decommissioning trust fund Goodwill Intangible assets Regulatory assets 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 Taxes accrued Interest accrued Customer deposits Mark-to-market derivative liabilities Current regulatory liabilities Other current liabilities Liabilities of discontinued operations (Note 16) Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes, net Accumulated deferred investment tax credits Regulatory liabilities Asset retirement obligations Pension and other postretirement benefits Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 10, 15 and 16) Ameren Corporation Stockholders’ Equity: Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 242.6 Other paid-in capital, principally premium on common stock Retained earnings Accumulated other comprehensive income (loss) Total Ameren Corporation stockholders’ equity Noncontrolling Interests Total equity TOTAL LIABILITIES AND EQUITY December 31, 2013 2012 $ $ $ 30 404 304 196 526 156 106 85 165 1,972 16,205 494 411 22 1,240 698 2,865 21,042 534 368 806 55 86 105 52 216 194 45 2,461 5,504 3,166 63 1,705 369 466 622 6,391 $ $ $ 184 354 291 71 570 247 170 98 1,611 3,596 15,348 408 411 14 1,786 667 3,286 22,230 355 - 533 49 89 107 92 100 168 1,193 2,686 5,802 3,186 70 1,589 349 1,138 643 6,975 2 5,632 907 3 6,544 142 6,686 21,042 $ 2 5,616 1,006 (8) 6,616 151 6,767 22,230 $ The accompanying notes are an integral part of these consolidated financial statements. 74 AMEREN CORPORATION CONSOLIDATED STATEMENT OF CASH FLOWS (In millions) Cash Flows From Operating Activities: Net income (loss) (Income) loss from discontinued operations, net of tax Adjustments to reconcile net income (loss) 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 Taum Sauk regulatory disallowance Other Changes in assets and liabilities: Receivables Materials and supplies Accounts and wages payable Taxes accrued Assets, other Liabilities, other Pension and other postretirement benefits Counterparty collateral, net Premiums paid on long-term debt repurchases Net cash provided by operating activities – continuing operations Net cash provided by operating activities – discontinued operations Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Nuclear fuel expenditures Purchases of securities – nuclear decommissioning trust fund Sales and maturities of securities – nuclear decommissioning trust fund Tax grants received related to renewable energy properties Other Net cash used in investing activities – continuing operations Net cash used in investing activities – discontinued operations Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends paid to noncontrolling interest holders Short-term debt and credit facility repayments, net Redemptions, repurchases, and maturities of long-term debt Issuances: Long-term debt Common stock Capital issuance costs Advances received for construction Repayments of advances received for construction Net cash used in financing activities – continuing operations Net cash used in financing activities – discontinued operations Net cash used in financing activities Net change in cash and cash equivalents Cash and cash equivalents at beginning of year Cash and cash equivalents at end of year Less: cash and cash equivalents at end of year – discontinued operations Cash and cash equivalents at end of year – continuing operations Noncash financing activity – dividends on common stock $ $ Year Ended December 31, 2012 2013 2011 295 223 666 71 24 410 (37) 27 - 23 (60) 60 81 (195) 2 33 (28) 41 - 1,636 57 1,693 (1,379) (45) (214) 196 - 2 (1,440) (283) (1,723) (388) (6) 368 (399) 278 - (2) 1 (1) (149) - (149) (179) 209 30 - 30 - $ (974) 1,496 $ 633 83 20 257 (36) 29 - (7) 30 (28) (34) (4) (6) 65 (23) 41 (138) 1,404 286 1,690 (1,063) (91) (403) 384 18 2 (1,153) (157) (1,310) (382) (6) (148) (760) 882 - (16) 4 - (426) - (426) (46) 255 209 25 184 (7) $ $ $ $ 526 (89) 602 61 16 262 (34) 17 89 1 200 (29) (28) (5) 59 (85) (100) 36 - 1,499 379 1,878 (881) (62) (220) 199 - 15 (949) (99) (1,048) (375) (6) (481) (155) - 65 - 5 (73) (1,020) (100) (1,120) (290) 545 255 7 248 - The accompanying notes are an integral part of these consolidated financial statements. 75 AMEREN CORPORATION CONSOLIDATED STATEMENT OF STOCKHOLDERS’ EQUITY (In millions) Common Stock: Beginning of year Shares issued Common stock, end of year Other Paid-in Capital: Beginning of year Shares issued Stock-based compensation activity Other paid-in capital, end of year Retained Earnings: Beginning of year Net income (loss) attributable to Ameren Corporation Dividends Retained earnings, end of year Accumulated Other Comprehensive Income (Loss): Derivative financial instruments, beginning of year Change in derivative financial instruments Divestiture of derivative financial instruments (Note 16) Derivative financial instruments, end of year Deferred retirement benefit costs, beginning of year Change in deferred retirement benefit costs Divestiture of deferred retirement benefit costs (Note 16) Deferred retirement benefit costs, end of year Total accumulated other comprehensive income (loss), end of year December 31, 2012 2013 2011 $ $ 2 - 2 $ 2 - 2 2 - 2 5,616 - 16 5,632 1,006 289 (388) 907 25 (21) (4) - (33) 29 7 3 3 5,598 - 18 5,616 2,369 (974) (389) 1,006 7 18 - 25 (57) 24 - (33) (8) 5,520 65 13 5,598 2,225 519 (375) 2,369 - 7 - 7 (17) (40) - (57) (50) Total Ameren Corporation Stockholders’ Equity $ 6,544 $ 6,616 $ 7,919 Noncontrolling Interests: Beginning of year Net income attributable to noncontrolling interest holders Dividends paid to noncontrolling interest holders Divestiture of noncontrolling interest (Note 16) Other Noncontrolling interests, end of year Total Equity Common stock shares at beginning of year Shares issued Common stock shares at end of year 151 6 (6) (9) - 142 149 - (6) - 8 151 154 7 (6) - (6) 149 $ 6,686 $ 6,767 $ 8,068 242.6 - 242.6 242.6 - 242.6 240.4 2.2 242.6 The accompanying notes are an integral part of these consolidated financial statements. 76 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF INCOME AND COMPREHENSIVE INCOME (In millions) Year Ended December 31, 2012 2013 2011 Operating Revenues: Electric Gas Other Total operating revenues Operating Expenses: Fuel Purchased power Gas purchased for resale Other operations and maintenance Taum Sauk regulatory disallowance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income and Expenses: Miscellaneous income Miscellaneous expense Total other income Interest Charges Income Before Income Taxes Income Taxes Net Income Other Comprehensive Income Comprehensive Income Net Income Preferred Stock Dividends Net Income Available to Common Stockholder $ 3,379 161 1 3,541 $ 3,132 139 1 3,272 $ 3,222 156 5 3,383 845 127 78 915 - 454 319 2,738 803 58 11 47 210 640 242 398 - 398 398 3 395 $ $ $ 714 78 64 827 - 440 304 866 104 77 934 89 408 296 2,427 845 2,774 609 63 14 49 223 671 252 419 - 419 419 3 416 $ $ $ 61 10 51 209 451 161 290 - 290 290 3 287 $ $ $ The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 77 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 $5 and $5, respectively) Accounts receivable – affiliates Unbilled revenue Miscellaneous accounts and notes receivable Materials and supplies Current regulatory assets Other current assets Total current assets Property and Plant, Net Investments and Other Assets: Nuclear decommissioning trust fund Intangible assets Regulatory assets Other assets Total investments and other assets TOTAL ASSETS LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities: Current maturities of long-term debt Borrowings from money pool Accounts and wages payable Accounts payable – affiliates Taxes accrued Interest accrued Current regulatory liabilities Other current liabilities Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes, net Accumulated deferred investment tax credits Regulatory liabilities Asset retirement obligations Pension and other postretirement benefits Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 10, 14 and 15) Stockholders’ 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 not subject to mandatory redemption Retained earnings Total stockholders’ equity December 31, 2013 2012 $ 1 - 191 1 168 57 352 118 71 959 10,452 494 22 534 443 $ 148 24 161 4 145 48 397 163 69 1,159 10,161 408 14 852 449 1,493 1,723 $ 12,904 $ 13,043 $ $ 109 105 387 30 220 57 57 82 1,047 3,648 2,509 59 1,041 366 189 52 4,216 511 1,560 80 1,842 3,993 205 - 345 66 28 60 18 77 799 3,801 2,443 64 917 346 461 158 4,389 511 1,556 80 1,907 4,054 TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY $ 12,904 $ 13,043 The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 78 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF CASH FLOWS (In millions) Year Ended December 31, 2012 2013 2011 Cash Flows From Operating Activities: Net income Adjustments to reconcile net income to net cash provided by operating activities: $ 398 $ 419 $ 290 Taum Sauk regulatory disallowance Depreciation and amortization Amortization of nuclear fuel FAC prudence review charges 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 Materials and supplies Accounts and wages payable Taxes accrued Assets, other Liabilities, other Pension and other postretirement benefits Premiums paid on long-term debt repurchases Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Nuclear fuel expenditures Purchases of securities – nuclear decommissioning trust fund Sales and maturities of securities – nuclear decommissioning trust fund Money pool advances, net Tax grants received related to renewable energy properties Other Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends on preferred stock Money pool borrowings, net Redemptions, repurchases, and maturities of long-term debt Issuances of long-term debt Capital issuance costs Capital contribution from parent Repayments of advances received for construction Net cash used in financing activities Net change in cash and cash equivalents Cash and cash equivalents at beginning of year Cash and cash equivalents at end of year Cash Paid (Refunded) During the Year: Interest (net of $16, $15, and $25 capitalized, respectively) Income taxes, net - 419 71 26 7 65 (31) 1 (59) 45 42 100 47 10 2 - - 407 83 - 6 287 (31) 8 27 (48) (27) (46) (35) 14 2 (62) 89 377 61 18 6 155 (30) (8) 66 (7) 12 (6) 79 (48) 2 - 1,143 1,004 1,056 (648) (45) (214) 196 24 - - (687) (460) (3) 105 (249) - - 4 - (603) (147) 148 1 212 86 $ $ (595) (91) (403) 384 (24) 18 8 (703) (400) (3) - (427) 482 (7) 1 - (354) (53) 201 148 220 (3) $ $ (550) (62) (220) 199 - - 6 (627) (403) (3) - (5) - - - (19) (430) (1) 202 201 210 9 $ $ The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 79 UNION ELECTRIC COMPANY (d/b/a AMEREN MISSOURI) STATEMENT OF STOCKHOLDERS’ 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 Not Subject to Mandatory Redemption Retained Earnings: Beginning of year Net income Common stock dividends Preferred stock dividends Retained earnings, end of year Total Stockholders’ Equity December 31, 2012 2013 2011 $ 511 $ 511 $ 511 1,556 4 1,560 80 1,907 398 (460) (3) 1,842 1,555 1 1,556 80 1,891 419 (400) (3) 1,907 1,555 - 1,555 80 2,007 290 (403) (3) 1,891 $ 3,993 $ 4,054 $ 4,037 The accompanying notes as they relate to Ameren Missouri are an integral part of these financial statements. 80 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF INCOME AND COMPREHENSIVE INCOME (In millions) Year Ended December 31, 2012 2013 2011 Operating Revenues: Electric Gas Other Total operating revenues Operating Expenses: Purchased power Gas purchased for resale Other operations and maintenance Depreciation and amortization Taxes other than income taxes Total operating expenses Operating Income Other Income and Expenses: Miscellaneous income Miscellaneous expense Total other income (expense) Interest Charges Income Before Income Taxes Income Taxes Net Income Other Comprehensive Loss, Net of Taxes: Pension and other postretirement benefit plan activity, net of income tax benefit of $(2), $(2) and $(2), respectively Comprehensive Income Net Income Preferred Stock Dividends Net Income Available to Common Stockholder $ $ $ $ 1,461 847 3 2,311 380 448 693 243 132 1,896 415 10 9 1 143 273 110 163 (3) 160 163 3 160 $ $ $ $ 1,739 786 - 2,525 705 408 684 221 130 2,148 377 $ 1,940 846 1 2,787 853 492 640 215 129 2,329 458 7 17 (10) 129 238 94 144 (3) 141 144 3 141 $ $ $ 7 6 1 136 323 127 196 (3) 193 196 3 193 The accompanying notes as they relate to Ameren Illinois are an integral part of these consolidated financial statements. 81 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 $13 and $12, respectively) Accounts receivable – affiliates Unbilled revenue Miscellaneous accounts receivable Materials and supplies Current regulatory assets Current accumulated deferred income taxes, net Other current assets Total current assets Property and Plant, Net Investments and Other Assets: Tax receivable – Genco Goodwill Regulatory assets Other assets Total investments and other assets TOTAL ASSETS LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities: Current maturities of long-term debt Borrowings from money pool Accounts and wages payable Accounts payable – affiliates Taxes accrued Customer deposits Mark-to-market derivative liabilities Current environmental remediation Current regulatory liabilities Other current liabilities Total current liabilities Long-term Debt, Net Deferred Credits and Other Liabilities: Accumulated deferred income taxes, net Accumulated deferred investment tax credits Regulatory liabilities Pension and other postretirement benefits Environmental remediation Other deferred credits and liabilities Total deferred credits and other liabilities Commitments and Contingencies (Notes 2, 14 and 15) Stockholders’ Equity: Common stock, no par value, 45.0 shares authorized – 25.5 shares outstanding Other paid-in capital Preferred stock not subject to mandatory redemption Retained earnings Accumulated other comprehensive income Total stockholders’ equity TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY December 31, 2013 2012 $ $ $ $ 1 201 - 135 13 174 38 45 26 633 5,589 - 411 701 120 1,232 7,454 - 56 243 18 23 79 36 43 159 114 771 1,856 1,116 4 664 197 232 166 2,379 - 1,965 62 410 11 2,448 7,454 $ $ $ $ - 182 10 146 22 173 84 85 47 749 5,052 39 411 934 97 1,481 7,282 150 24 146 86 18 85 77 37 82 92 797 1,577 1,025 5 672 406 216 183 2,507 - 1,965 62 360 14 2,401 7,282 The accompanying notes as they relate to Ameren Illinois are an integral part of these consolidated financial statements. 82 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 Other Changes in assets and liabilities: Receivables Materials and supplies Accounts and wages payable Taxes accrued Assets, other Liabilities, other Pension and other postretirement benefits Counterparty collateral, net Premiums paid on long-term debt repurchases Net cash provided by operating activities Cash Flows From Investing Activities: Capital expenditures Returns from ATXI for construction Other Net cash used in investing activities Cash Flows From Financing Activities: Dividends on common stock Dividends on preferred stock Money pool borrowings, net Redemptions, repurchases, and maturities of long-term debt Issuances of long-term debt Capital issuance costs Repayments of advances received for construction Advances received for construction Capital contribution from parent Net cash provided by (used in) financing activities Net change in cash and cash equivalents Cash and cash equivalents at beginning of year Cash and cash equivalents at end of year Cash Paid (Refunded) During the Year: Interest (net of $4, $2, and $2 capitalized, respectively) Income taxes, net Year Ended December 31, 2011 2012 2013 $ 163 $ 144 $ 196 238 15 104 4 50 15 19 28 (53) 33 (8) 43 - 214 11 104 (11) 23 20 (21) 3 22 72 (26) 40 (76) 651 519 (701) - 6 (695) (110) (3) 32 (150) 278 (2) (1) 1 - 45 1 - 1 112 (23) $ $ (442) - 5 (437) (189) (3) 24 (333) 400 (6) - 4 - (103) (21) 21 - 125 (22) $ $ $ $ 206 8 155 (14) 146 (21) (46) (12) (3) (30) (101) 20 - 504 (351) 49 6 (296) (327) (3) - (150) - - (53) 5 19 (509) (301) 322 21 137 (14) The accompanying notes as they relate to Ameren Illinois are an integral part of these consolidated financial statements. 83 AMEREN ILLINOIS COMPANY (d/b/a AMEREN ILLINOIS) STATEMENT OF STOCKHOLDERS’ 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 Not Subject to Mandatory Redemption Retained Earnings: Beginning of year Net income Common stock dividends Preferred stock dividends Retained earnings, end of year Accumulated Other Comprehensive Income: Deferred retirement benefit costs, beginning of year Change in deferred retirement benefit costs Deferred retirement benefit costs, end of year Total accumulated other comprehensive income, end of year December 31, 2012 2013 2011 $ - $ - $ - 1,965 - 1,965 1,965 - 1,965 62 62 360 163 (110) (3) 410 14 (3) 11 11 408 144 (189) (3) 360 17 (3) 14 14 1,952 13 1,965 62 542 196 (327) (3) 408 20 (3) 17 17 Total Stockholders’ Equity $ 2,448 $ 2,401 $ 2,452 The accompanying notes as they relate to Ameren Illinois are an integral part of these consolidated financial statements. 84 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, 2013 NOTE 1 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES General Ameren, headquartered in St. Louis, Missouri, is a public utility holding company under PUHCA 2005, administered by FERC. Ameren’s 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 other expenses by Ameren depend on distributions made to it by its subsidiaries. Ameren’s principal subsidiaries are listed below. ‰ ‰ Union Electric Company, doing business as Ameren Missouri, operates a rate-regulated electric generation, transmission, and distribution business, and a rate- regulated natural gas transmission and 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. This area has an estimated population of 2.8 million and includes the Greater St. Louis area. Ameren Missouri supplies electric service to 1.2 million customers and natural gas service to 127,000 customers. Ameren Illinois Company, doing business as Ameren Illinois, operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. Ameren Illinois was created by the merger of CILCO and IP with and into CIPS in 2010. CIPS 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 portions of central and southern Illinois having an estimated population of 3.1 million in an area of 40,000 square miles. Ameren Illinois supplies electric service to 1.2 million customers and natural gas service to 767,000 customers. Ameren has various other subsidiaries responsible for activities such as the provision of shared services. Ameren also has a subsidiary, ATXI, that operates a FERC rate- regulated electric transmission business and is developing the Illinois Rivers project. the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. As a result of the transaction agreement with IPH and Ameren’s plan to sell its Elgin, Gibson City, and Grand Tower gas-fired energy centers, Ameren determined that New AER and the gas-fired energy centers qualified for discontinued operations presentation beginning March 14, 2013. In addition, as of December 2, 2013, Ameren abandoned the Meredosia and Hutsonville energy centers upon the completion of the divestiture of New AER to IPH. Ameren is prohibited from operating these energy centers through December 31, 2020, as a provision of the Illinois Pollution Control Board’s November 2013 order granting IPH a variance of the MPS. As a result, Ameren determined that the Meredosia and Hutsonville energy centers qualified for discontinued operations presentation as of December 2, 2013. The Meredosia and Hutsonville energy centers ceased operations at December 31, 2011, and therefore 2011 was the last year those energy centers had a material effect on Ameren’s consolidated financial statements. As a result of these events, Ameren has segregated New AER’s and the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers’ operating results, assets, and liabilities and presented them separately as discontinued operations for all periods presented in this report. Unless otherwise stated, these notes to the financial statements exclude discontinued operations for all periods presented. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information regarding that presentation. The financial statements of Ameren are prepared on a consolidated basis, and therefore include the accounts of its majority-owned subsidiaries. Ameren Missouri and Ameren Illinois have no subsidiaries and therefore their financial statements are not prepared on a consolidated basis. All significant intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated. Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) that are necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements, and the reported amounts of revenues and expenses during the reported periods. Actual results could differ from those estimates. Regulation On March 14, 2013, Ameren entered into a transaction Certain Ameren subsidiaries are regulated by the agreement to divest New AER to IPH. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. On January 31, 2014, Medina Valley completed its sale of MoPSC, the ICC, and FERC. In accordance with authoritative accounting guidance regarding accounting for the effects of certain types of regulation, Ameren Missouri 85 and Ameren Illinois defer certain costs as assets pursuant to actions of rate regulators or because of expectations that the companies will be able to recover such costs in rates charged to customers. Ameren Missouri and Ameren Illinois also defer certain amounts as liabilities pursuant to actions of rate regulators or based on the expectation that such amounts will be returned to customers in future rates. Regulatory assets and liabilities are amortized consistent with the period of expected regulatory treatment. In addition to the cost recovery mechanisms discussed in the Purchased Gas, Power and Fuel Rate-adjustment Mechanisms section below, Ameren Missouri and Ameren Illinois have approvals from regulators to use other cost recovery mechanisms. Ameren Missouri has a vegetation management and infrastructure inspection cost tracker, a pension and postretirement benefit cost tracker, an uncertain tax positions tracker, a renewable energy standards cost tracker, a storm restoration cost tracker, and the MEEIA energy efficiency rider. In addition to participating in the IEIMA’s formula rate regulatory framework, Ameren Illinois has an environmental cost rider, an asbestos-related litigation rider, an energy efficiency rider, and a bad debt rider. See Note 2 – Rate and Regulatory Matters for additional information on regulatory assets and liabilities. In addition, other costs that Ameren Materials and Supplies Missouri and Ameren Illinois expect to recover from customers are recorded as construction work in progress and property and plant, net. See Note 3 – Property and Plant, Net. Cash and Cash Equivalents Cash and cash equivalents include cash on hand and temporary investments purchased with an original maturity of three months or less. 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 a rate mechanism that adjusts rates for net write-offs of customer accounts receivable above or below those being collected in rates. Materials and supplies are recorded at the lower of cost or market. Cost is determined using the average-cost method. Materials and supplies are capitalized as inventory when purchased and then expensed or capitalized as plant assets when installed, as appropriate. The following table presents a breakdown of materials and supplies for each of the Ameren Companies at December 31, 2013, and 2012: 2013 Fuel(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gas stored underground . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other materials and supplies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Fuel(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gas stored underground . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other materials and supplies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) Consists of coal, oil, and propane. Property and Plant Depreciation Ameren Missouri Ameren Illinois Ameren $ $ $ $ 144 17 191 352 198 18 181 397 $ $ $ $ - 110 64 174 - 113 60 173 $ $ $ $ 144 127 255 526 198 131 241 570 We capitalize the cost of additions to and betterments of units of property and plant. 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, including nuclear refueling and maintenance outages, are expensed as incurred. When units of depreciable property are retired, the original costs, less salvage values, are charged to accumulated depreciation. Asset removal costs accrued by our rate-regulated operations that do not constitute legal obligations are classified as a regulatory liability. See Asset Retirement Obligations below and Note 3 – Property and Plant, Net, for additional information. 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 provision for depreciation for the Ameren Companies in 2013, 2012 and 2011 ranged from 3% to 4% of the average depreciable cost. Allowance for Funds Used During Construction We capitalize allowance for funds used during construction, or the cost of borrowed funds and the cost of equity funds (preferred and common stockholders’ equity) 86 applicable to rate-regulated construction expenditures, in accordance with the utility industry’s accounting practice. Allowance for funds used during construction does not represent a current source of cash funds. This accounting practice offsets the effect on earnings of the cost of financing during construction, and it treats such financing costs in the same manner as construction charges for labor and materials. 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. The following table presents the annual allowance for funds used during construction rates that were utilized during 2013, 2012 and 2011: Ameren Missouri . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . 8% 8% 8% 9% 8% 9% 2013 2012 2011 Goodwill and Intangible Assets 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 recorded goodwill of $411 million at December 31, 2013, and 2012. Ameren has two reporting units, which also represent Ameren’s reportable segments. Ameren’s reporting units are Ameren Missouri and Ameren Illinois. Ameren Illinois has one reporting unit, Ameren Illinois. Ameren’s and Ameren Illinois’ reporting units have been defined and goodwill has been evaluated at the operating segment level in accordance with authoritative accounting guidance. Our reporting units represent businesses for which discrete financial information is available and reviewed regularly by management. All of Ameren’s and Ameren Illinois’ goodwill at December 31, 2013, and 2012, has been assigned to the Ameren Illinois reporting unit. We evaluate goodwill for impairment as of October 31 of each year, or more frequently if events and circumstances indicate that the asset might be impaired. Ameren and Ameren Illinois applied a qualitative goodwill evaluation model for their annual goodwill impairment test conducted as of October 31, 2013. Based on the results of Ameren’s and Ameren Illinois’ qualitative assessment, Ameren and Ameren Illinois believe it was more likely than not that the fair value of the Ameren Illinois reporting unit exceeded its carrying value as of October 31, 2013, indicating no impairment of Ameren’s or Ameren Illinois’ goodwill. The following factors, among others, were considered by Ameren and Ameren Illinois when assessing whether it was more likely than not that the fair value of the Ameren Illinois reporting unit exceeded its carrying value for the October 31, 2013, test: ‰ macroeconomic conditions, including those conditions within Ameren Illinois’ service territory; ‰ ‰ ‰ ‰ ‰ pending rate case outcomes and projections of future rate case outcomes; changes in laws and potential law changes; observable industry market multiples; achievement of IEIMA performance metrics and the yield of the 30-year United States treasury bonds; and actual and forecasted financial performance. The goodwill assigned to the Ameren Illinois reporting unit on the December 31, 2013, balance sheets of Ameren and Ameren Illinois had no accumulated goodwill impairment losses. Ameren and Ameren Illinois will continue to monitor the actual and forecasted operating results, cash flows, market capitalization, and observable industry market multiples of the Ameren Illinois reporting unit for signs of possible declines in estimated fair value and potential goodwill impairment. Intangible Assets. Ameren and Ameren Missouri classify emission allowances and renewable energy credits as intangible assets. Ameren Illinois consumes renewable energy credits as they are purchased through the IPA procurement process and expenses them immediately. We evaluate intangible assets for impairment if events or changes in circumstances indicate that their carrying amount might be impaired. At December 31, 2013, Ameren’s and Ameren Missouri’s intangible assets consisted of renewable energy credits obtained through wind and solar power purchase agreements. The book value of Ameren’s and Ameren Missouri’s renewable energy credits was $22 million and $22 million at December 31, 2013, respectively. The book value of Ameren’s and Ameren Missouri’s renewable energy credits was $14 million and $14 million at December 31, 2012, respectively. Renewable energy credits and emission allowances are charged to purchased power expense and fuel expense, respectively, as they are used in operations. In accordance with the MoPSC’s 2012 electric rate order, most of Ameren Missouri’s amortization of intangible assets is deferred as a regulatory asset pending future recovery from customers through rates. The following table presents amortization expense based on usage of renewable energy credits and emission allowances, net of gains from sales, for Ameren, Ameren Missouri, and Ameren Illinois during the years ended December 31, 2013, 2012, and 2011. 2013 2012 2011 Ameren Missouri . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . $ $ (a) 13 13 $ $ (a) 4 4 $ $ (a) 3 3 (a) Less than $1 million. 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 impairment has 87 occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets with the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, we recognize an impairment charge equal to the amount of the carrying value that exceeds the estimated fair value of the assets. In the period in which we determine an asset meets held for sale criteria, we record an impairment charge to the extent the book value exceeds its fair value less cost to sell. During 2011, the MoPSC issued an electric rate order that disallowed the recovery of all costs of enhancements, or costs that would have been incurred absent the breach, related to the rebuilding of the Taum Sauk energy center in excess of the amount recovered from property insurance. Consequently, Ameren and Ameren Missouri each recorded a pretax charge to earnings of $89 million, which is reflected as “Taum Sauk regulatory disallowance” on each company’s statement of income. Investments Ameren and Ameren Missouri evaluate for impairment the investments held in Ameren Missouri’s nuclear decommissioning trust fund. Losses on assets in the trust fund could result in higher funding requirements for decommissioning costs, which Ameren Missouri believes would be recovered in electric rates paid by its customers. Accordingly, Ameren and Ameren Missouri recognize a regulatory asset on their balance sheets for losses on investments held in the nuclear decommissioning trust fund. See Note 9 – Nuclear Decommissioning Trust Fund Investments for additional information. 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. If environmental expenditures are related to facilities currently in use, such as pollution control equipment, the cost is capitalized and depreciated over the expected life of the asset. Unamortized Debt Discount, Premium, and Expense Discount, premium, and expense associated with long- term debt are amortized over the lives of the related issues. Revenue Operating Revenues The Ameren Companies record operating revenue for electric or natural gas service when it is delivered to customers. We accrue an estimate of electric and natural gas revenues for service rendered but unbilled at the end of each accounting period. Beginning in 2012, Ameren Illinois elected to participate in the performance-based formula ratemaking framework pursuant to the IEIMA. The IEIMA provides for an annual reconciliation of Ameren Illinois’ electric distribution revenue requirement. As of each balance sheet date, Ameren Illinois records its estimate of the electric distribution revenue impact resulting from the reconciliation of the revenue requirement necessary to reflect the actual costs incurred for that year with the revenue requirement that was in effect for billing purposes for that year. If the current year’s revenue requirement is greater than the revenue requirement customer rates were based upon, an increase to electric operating revenues with an offset to a regulatory asset is recorded to reflect the expected recovery of those additional costs from customers within the next two years. If the current year’s revenue requirement is less than the revenue requirement customer rates were based upon, a reduction to electric operating revenues with an offset to a regulatory liability is recorded to reflect the expected refund to customers within the next two years. See Note 2 – Rate and Regulatory Matters for information regarding Ameren Illinois’ revenue requirement reconciliation pursuant to the IEIMA. Similar to the IEIMA process described above, Ameren Illinois and ATXI record the impact of a revenue requirement reconciliation for each company’s electric transmission jurisdiction, pursuant to FERC-approved rate treatment. Nuclear Fuel Ameren Missouri’s cost of nuclear fuel is capitalized and then amortized to fuel expense on a unit-of-production basis. Spent fuel disposal cost is based on net kilowatthours generated and sold. That cost is charged to “Operating Expenses – Fuel” in the statement of income. Purchased Gas, Power and Fuel Rate-adjustment Mechanisms Ameren Missouri and Ameren Illinois have various rate-adjustment mechanisms in place that provide for the recovery of purchased natural gas and electric fuel and purchased power costs. See Note 2 – Rate and Regulatory Matters for the regulatory assets and liabilities recorded at December 31, 2013, and 2012, related to the rate- adjustment mechanisms discussed below. In Ameren Missouri’s and Ameren Illinois’ retail natural gas utility jurisdictions, changes in natural gas costs are reflected in billings to their natural gas utility customers through PGA clauses. The differences between actual natural gas costs and costs billed to customers in a given period are deferred as regulatory assets or liabilities. The deferred amounts are either billed or refunded to natural gas utility customers in a subsequent period. In Ameren Illinois’ retail electric utility jurisdictions, changes in purchased power and transmission service costs are reflected in billings to their electric utility customers through pass-through rate-adjustment clauses. The differences between actual purchased power and transmission service costs and costs billed to customers in 88 a given period are deferred as regulatory assets or liabilities. The deferred amounts are either billed or refunded to electric utility customers in a subsequent period. Ameren Missouri has a FAC that allows an adjustment of electric rates three times per year for a pass-through to customers of 95% of changes in fuel, certain fuel additives, emission allowances, purchased power costs, transmission costs and revenues, and MISO costs and revenues, net of off-system sales revenues, greater or less than the amount set in base rates without a traditional rate proceeding, subject to MoPSC prudency review. The differences between the cost of fuel incurred and the cost of fuel recovered from Ameren Missouri customers’ base rates are deferred as regulatory assets or liabilities. The deferred amounts are either billed or refunded to Ameren Missouri’s electric utility customers in a subsequent period. Accounting for MISO Transactions MISO-related purchase and sale transactions are recorded by Ameren, Ameren Missouri and Ameren Illinois using settlement information provided by 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 and Ameren Illinois prior-period transactions will be resettled outside the routine settlement process because of a change in MISO’s tariff or a material interpretation thereof. In these cases, Ameren Missouri and Ameren Illinois recognize expenses associated with resettlements once the resettlement is probable and the resettlement amount can be estimated, and the Ameren Companies recognize revenues once the resettlement amount is received. Stock-based Compensation Stock-based compensation cost is measured at the grant date based on the fair value of the award. Ameren recognizes as compensation expense the estimated fair value of stock-based compensation on a straight-line basis over the requisite service period. See Note 12 – Stock- based Compensation for additional information. Excise Taxes Excise taxes levied on us are reflected on Ameren Missouri electric customer bills and on Ameren Missouri and Ameren Illinois natural gas customer bills. They are recorded gross in “Operating Revenues – Electric,” “Operating Revenues – Gas” and “Operating Expenses – Taxes other than income taxes” on the statement of income (loss). Excise taxes reflected on Ameren Illinois electric customer bills are imposed on the customer and are therefore not included in revenues and expenses. They are included in “Taxes accrued” on the balance sheet. The following table presents excise taxes recorded in “Operating Revenues – Electric,” “Operating Revenues – Gas,” and “Operating Expenses – Taxes other than income taxes” for the years ended 2013, 2012 and 2011: 2013 2012 2011 Ameren Missouri . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . $ $ 152 61 213 $ $ 139 54 193 $ $ 137 57 194 Income Taxes Ameren uses an asset and liability approach for its financial accounting and reporting of income taxes, in accordance with authoritative accounting guidance. 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 recognize that regulators will probably reduce future revenues for deferred tax liabilities that were initially recorded at rates in excess of the current statutory rate. Therefore, reductions in the deferred tax liability, which 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 in rates of future income taxes, resulting from the reversal of the equity portion of the allowance for funds used during construction that was an unrecognized temporary difference prior to the adoption of the authoritative accounting guidance for income taxes. Investment tax credits used on tax returns for prior years have been deferred in accordance with GAAP. The credits are being amortized over the useful lives of the related investment. Deferred income taxes were recorded on the temporary difference represented by the deferred investment tax credits and a corresponding regulatory liability. This recognizes the expected reduction in rate revenue for future lower income taxes associated with the amortization of the investment tax credits. See Note 13 – Income Taxes. For certain renewable energy construction projects placed in service, Ameren Missouri elected to seek federal tax grants in lieu of the investment tax credits for which the projects also qualified. These grants were accounted for using a grant recognition accounting model. Ameren Missouri elected to reduce the basis of property as grants were received, which will reduce the amount of depreciation expense recognized in future periods. In 2012, Ameren Missouri received $18 million in federal tax grants. Ameren Missouri, Ameren Illinois, and all the other Ameren subsidiary companies are parties to a tax allocation agreement with Ameren that provides for the allocation of consolidated tax liabilities. The tax allocation agreement specifies that each party be allocated an amount of tax 89 similar to that which would be owed had the party been separately subject to tax. Any net benefit attributable to the parent is reallocated to other members. That allocation is treated as a contribution of capital to the party receiving the benefit. Noncontrolling Interests As of December 31, 2013, Ameren’s noncontrolling interests included the preferred stock not subject to mandatory redemption of Ameren Missouri and Ameren Illinois. As of December 31, 2012, Ameren’s noncontrolling interests also included the 20% of EEI not owned by Ameren. All noncontrolling interests are classified as a component of equity separate from Ameren’s equity in its consolidated balance sheet. Earnings per Share Basic earnings per share is computed by dividing net income attributable to Ameren Corporation by the weighted-average number of common shares outstanding during the period. Diluted earnings per share is computed by dividing net income attributable to Ameren Corporation by the diluted weighted-average number of common shares outstanding during the period. Diluted earnings per share reflects the potential dilution that would occur if certain stock-based performance share units were settled. The following table presents Ameren’s basic and diluted earnings per share calculations and 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, 2013, 2012 and 2011: Net income (loss) attributable to Ameren Corporation: Continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Average common shares outstanding – basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Assumed settlement of performance share units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Average common shares outstanding – diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Earnings (loss) per common share – basic: Continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Earnings (loss) per common share – basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Earnings (loss) per common share – diluted: Continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Earnings (loss) per common share – diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Average performance share units excluded from calculation(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2013 2012 2011 $ $ $ $ $ $ 512 (223) 289 242.6 1.9 244.5 2.11 (0.92) 1.19 2.10 (0.92) 1.18 0.1 $ $ $ $ $ $ 516 (1,490) $ (974) $ 242.6 0.4 243.0 $ 2.13 (6.14) (4.01) $ $ 2.13 (6.14) (4.01) $ 0.7 431 88 519 241.5 0.6 242.1 1.79 0.36 2.15 1.79 0.36 2.15 - (a) Weighted-average number of performance share units that were excluded from the “Assumed settlement of performance share units” provided above because the performance or market conditions related to the awards had not yet been met. Supplemental Cash Flow Information See Note 3 – Property and Plant, Net, for information The following table presents additional information regarding Ameren’s consolidated statement of cash flows for the years ended December 31, 2013, 2012 and 2011: 2013 2012 2011 Cash paid (refunded) during the year: Interest Continuing operations(a) . . . . . . . . Discontinued operations(b) . . . . . . Income taxes, net Continuing Operations . . . . . . . . . Discontinued Operations . . . . . . . $ $ $ $ 362 31 393 116 (108) 8 $ $ $ $ 384 49 433 10 (9) 1 $ $ $ $ 393 60 453 (47) (14) (61) (a) Net of $ 20 million, $17 million, and $27 million capitalized, respectively. (b) Net of $ 17 million, $13 million, and $3 million capitalized, respectively. on accrued capital expenditures. Accounting Changes and Other Matters The following is a summary of recently adopted authoritative accounting guidance, as well as guidance issued but not yet adopted, that could affect the Ameren Companies. Presentation of Comprehensive Income In June 2011, FASB amended its guidance on the presentation of comprehensive income in financial statements. The amended guidance changed the presentation of comprehensive income in the financial statements. It requires entities to report components of comprehensive income either in a continuous statement of comprehensive income or in two separate but consecutive 90 statements. This guidance was effective for the Ameren Companies beginning in the first quarter of 2012 with retroactive application required. The implementation of the amended guidance did not affect the Ameren Companies’ results of operations, financial position, or liquidity. In February 2013, FASB amended this guidance to require an entity to provide information about the amounts reclassified out of accumulated OCI by component. In addition, an entity is required to present significant amounts reclassified out of accumulated OCI by the respective line items of net income either on the face of the statement where net income is presented or in the footnotes. This guidance was effective for the Ameren Companies beginning in the first quarter of 2013. The implementation of this amended guidance did not affect the Ameren Companies’ results of operations, financial position, or liquidity. The amounts reclassified out of accumulated OCI for the Ameren Companies corresponding to continuing operations related to pension and other postretirement plan activity. These amounts were immaterial for the year ended December 31, 2013, and therefore no additional disclosures were required. Disclosures about Offsetting Assets and Liabilities In December 2011, FASB issued additional authoritative accounting guidance to improve information disclosed about financial and derivative instruments. The guidance requires an entity to disclose information about offsetting and related arrangements to enable users of the financial statements to understand the effect of those arrangements on its financial position. In January 2013, FASB amended this guidance to limit the scope to derivative instruments, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions. The Ameren Companies adopted this guidance for the first quarter of 2013. The implementation of this additional guidance did not affect the Ameren Companies’ results of operations, financial positions, or liquidity, as this guidance only requires additional disclosures. See Note 7 – Derivative Financial Instruments for the required additional disclosures. Presentation of an Unrecognized Tax Benefit In July 2013, FASB issued additional authoritative accounting guidance to provide clarity for the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. It requires entities to present an unrecognized tax benefit as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward to the extent a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is available under the tax law. Currently, any unrecognized tax benefit is recorded in “Other deferred credits and liabilities” on Ameren’s, Ameren Missouri’s, and Ameren Illinois’ balance sheets. After this guidance becomes effective, any unrecognized tax benefit will be recorded in “Accumulated deferred income taxes, net” as a reduction to the deferred tax assets for net operating loss, a similar tax loss, and tax credit carryforwards on the respective balance sheets. At December 31, 2013, unrecognized tax benefits of $48 million and $15 million would have been recorded in “Accumulated deferred income taxes, net” at Ameren and Ameren Missouri, respectively under this new guidance. To the extent that an unrecognized tax benefit exceeds these carryforwards, the excess would continue to be recorded in “Other deferred credits and liabilities” on the respective balance sheets, consistent with current authoritative accounting guidance. The amended guidance will not affect the Ameren Companies’ results of operations or liquidity, as this guidance is presentation-related only. This guidance will be effective for the Ameren Companies beginning in the first quarter of 2014. Asset Retirement Obligations Authoritative accounting guidance requires us to 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 to capitalize a corresponding amount as part of the book value of the related long-lived asset. In subsequent periods, we are required to make adjustments to AROs based on changes in the estimated fair values of the obligations. Corresponding increases in asset book values are depreciated over the remaining useful life of the related asset. Uncertainties as to the probability, timing, or amount of cash flows associated with AROs affect our estimates of fair value. Ameren and Ameren Missouri have recorded AROs for retirement costs associated with Ameren Missouri’s Callaway energy center decommissioning costs, asbestos removal, CCR storage facilities, and river structures. Also, Ameren and Ameren Illinois have recorded AROs for retirement costs associated with asbestos removal. In addition, Ameren, Ameren Missouri and Ameren Illinois have recorded AROs for the disposal of certain transformers. Asset removal costs accrued by our rate-regulated operations that do not constitute legal obligations are classified as a regulatory liability. See Note 2 – Rate and Regulatory Matters. 91 The following table provides a reconciliation of the beginning and ending carrying amount of AROs for the years ended December 31, 2013, and 2012: Ameren Missouri(a) Ameren Illinois(b) Ameren(a) Balance at December 31, 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities incurred . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities settled . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accretion in 2012(d) Change in estimates(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 328 - (1) 18 1 $ 3 - (c) (c) (c) Balance at December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 346 $ 3 Liabilities incurred . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities settled . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accretion in 2013(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in estimates(e) - (1) 19 2 - (c) (c) (c) $ 331 - (1) 18 1 $ 349 - (1) 19 2 Balance at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 366 $ 3 $ 369 (a) The nuclear decommissioning trust fund assets of $494 million and $408 million as of December 31, 2013, and 2012, respectively, are restricted for decommissioning of the Callaway energy center. (b) Balance included in “Other deferred credits and liabilities” on the balance sheet. (c) Less than $1 million. (d) Accretion expense was recorded as an increase to regulatory assets at Ameren Missouri and Ameren Illinois. (e) Ameren Missouri changed its fair value estimates for asbestos removal in 2012 and 2013, and for certain CCR storage facilities in 2013. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the AROs related to the abandoned Meredosia and Hutsonville energy centers, which are presented as discontinued operations and therefore not included in the table above. Employee Separation Charges Missouri During the fourth quarter of 2011, Ameren Missouri FAC Prudence Review and Ameren Services extended voluntary separation offers consistent with Ameren’s standard management separation program to eligible management and labor union- represented employees. Approximately 340 employees of Ameren Missouri and Ameren Services accepted the offers and left their employment by December 31, 2011. Ameren and Ameren Missouri recorded a pretax charge to earnings of $28 million and $27 million, respectively, for the severance costs related to these offers. These charges were recorded in “Other operations and maintenance” expense in each company’s statement of income for the year ended December 31, 2011. Substantially all of the severance costs were paid in the first quarter of 2012. The severance costs related to participating Ameren Services employees were allocated to affiliates consistent with the terms of its support services agreement, which is described in Note 14 – Related Party Transactions. NOTE 2 – RATE AND REGULATORY MATTERS Below is a summary of significant regulatory proceedings and related lawsuits. We are unable to predict the ultimate outcome of these matters, the timing of the final decisions of the various agencies and courts, or the impact on our results of operations, financial position, or liquidity. In April 2011, the MoPSC issued an order with respect to its review of Ameren Missouri’s FAC for the period from March 1, 2009, to September 30, 2009. In this order, the MoPSC ruled that Ameren Missouri should have included in the FAC calculation all revenues and costs associated with certain long-term partial requirements sales that were made by Ameren Missouri because of the loss of Noranda’s load caused by a severe ice storm in January 2009. As a result of the order, Ameren Missouri recorded a pretax charge to earnings of $18 million, including $1 million for interest, in 2011 for its obligation to refund to its electric customers the earnings associated with these sales previously recognized by Ameren Missouri during the period from March 1, 2009, to September 30, 2009. In May 2012, upon appeal by Ameren Missouri, the Cole County Circuit Court reversed the MoPSC’s April 2011 order. In June 2012, the MoPSC and a group of large industrial customers filed an appeal of the Cole County Circuit Court’s ruling to the Missouri Court of Appeals, Western District. In May 2013, the Missouri Court of Appeals upheld the MoPSC’s April 2011 order and reversed the Cole County Circuit Court’s May 2012 decision. Ameren Missouri’s FAC calculation for the period from October 1, 2009, to May 31, 2011, excluded all revenues and costs associated with certain long-term partial requirements sales that were made by Ameren Missouri because of the loss of Noranda’s load caused by a severe ice storm in January 2009, similar to the FAC calculation for the period from March 1, 2009, to September 30, 2009. The MoPSC issued an order in July 2013, which was similar to 92 the MoPSC’s April 2011 order, as a result of which Ameren Missouri recorded a pretax charge to earnings of $26 million, including $1 million for interest, in 2013 for its estimated obligation to refund to Ameren Missouri’s electric customers the earnings associated with these sales previously recognized by Ameren Missouri for the period from October 1, 2009, to May 31, 2011. Ameren Missouri recorded the charge to “Operating Revenues – Electric” and the related interest to “Interest Charges” with a corresponding offset to “Current regulatory liabilities.” No similar revenues were excluded from FAC calculations after May 2011. Separately, in July 2011, Ameren Missouri filed a request with the MoPSC for an accounting authority order that would allow Ameren Missouri to defer fixed costs totaling $36 million that were not previously recovered from Noranda as a result of the loss of load caused by the severe 2009 ice storm for potential recovery in a future electric rate case. In November 2013, the MoPSC issued an order approving Ameren Missouri’s request for an accounting authority order. Ameren Missouri will seek to recover these fixed costs in its next electric rate case. In February 2014, MIEC filed an appeal of the accounting authority order to the Missouri Court of Appeals, Western District. 2012 Electric Rate Order In December 2012, the MoPSC issued an order approving an increase for Ameren Missouri in annual revenues for electric service of $260 million. The revenue increase was based on a 9.8% return on equity, a capital structure composed of 52.3% common equity, and a rate base of $6.8 billion. Rate changes consistent with the order became effective on January 2, 2013. In January 2013, Ameren Missouri appealed the order with respect to the amount of property taxes included in the order to the Missouri Court of Appeals, Western District. Later in 2013, Ameren Missouri withdrew this appeal. In February 2013, the MoOPC, MIEC, and other parties filed separate appeals to the Missouri Court of Appeals, Western District, relating to the order’s treatment of transmission costs in the FAC. In October 2013, the Missouri Court of Appeals, Western District, upheld the order. MoOPC, MIEC, and other parties filed a request to transfer their appeal to the Missouri Supreme Court, which was subsequently denied. MEEIA Order The MoPSC’s December 2012 electric rate order approved Ameren Missouri’s implementation of MEEIA megawatthour savings targets, energy efficiency programs, and associated cost recovery mechanisms and incentive awards. A MEEIA rider allows Ameren Missouri to collect from or refund to customers any annual difference in the actual amounts incurred and the projected amounts collected from customers for the MEEIA program costs and its projected lost revenues. In addition to the program costs and lost revenues discussed above, the terms of Ameren Missouri’s MoPSC- approved MEEIA programs offer an incentive award that would allow Ameren Missouri to earn additional revenues by achieving certain energy efficiency goals, including approximately $19 million if 100% of its energy efficiency goals are achieved during the three-year period, with the potential to earn more if Ameren Missouri’s energy savings exceed those goals. Ameren Missouri must achieve at least 70% of its energy efficiency goals before it earns any incentive award. The recovery of an incentive award from customers, if the energy efficiency goals are achieved, is expected in 2017 through the above-mentioned rider. Rate Design and Earnings Complaint Cases On February 13, 2014, Ameren Missouri’s largest customer, Noranda, and 37 residential customers filed an earnings complaint case and a rate design complaint case with the MoPSC. In the earnings complaint case, Noranda and the residential customers asserted that Ameren Missouri’s electric delivery service business is earning more than the 9.8% return on equity authorized in the MoPSC’s December 2012 electric rate order and requested the MoPSC to approve a reduction of the authorized return on equity to 9.4%. The rate design complaint case seeks to reduce Noranda’s electricity cost with an offsetting increase in electricity cost for Ameren Missouri’s other customers. The rate design complaint case asks the MoPSC to expedite its decision and grant relief by August 1, 2014. The MoPSC has ordered Ameren Missouri to file a response to these two complaints by March 17, 2014. The MoPSC has no time requirement by which it must issue an order in these cases. Ameren Missouri opposes both requests filed by Noranda and the residential customers and will vigorously defend itself. Illinois IEIMA Under the provisions of the IEIMA, Ameren Illinois’ electric delivery service rates effective for customers’ billings in 2013 were subject to an annual revenue requirement reconciliation to its actual 2013 costs. The 2013 revenue requirement reconciliation will be filed with the ICC in 2014. The approved annual revenue requirement reconciliation adjustment relating to 2013 will be reflected in customer rates beginning in January 2015. Throughout the year, Ameren Illinois records a regulatory asset or a regulatory liability and a corresponding increase or decrease to operating revenues for any differences between the revenue requirement in effect for that year and its estimate of the probable increase or decrease in the revenue requirement expected to ultimately be approved by the ICC based on that year’s actual costs incurred. As of December 31, 2013, Ameren Illinois recorded a $65 million regulatory asset to reflect its expected 2013 revenue requirement reconciliation adjustment, which will be recovered from customers in 2015. Ameren Illinois also recorded a regulatory liability of $65 million and $55 million as of December 31, 2013, and December 31, 2012, respectively, to reflect its 2012 revenue requirement reconciliation adjustment, with interest, which will be refunded to customers in 2014. 93 In May 2013, Illinois enacted into law certain amendments to the IEIMA that modified its implementation. The law clarified that the IEIMA requires that the year-end rate base must be used to calculate the revenue requirement reconciliation and that the interest applied to the revenue requirement reconciliation and return on equity collar adjustments must be equal to a company’s weighted- average return calculated under the formula rate. In September 2012, the ICC issued an order in Ameren Illinois’ initial filing under the IEIMA’s performance-based formula rate framework, which Ameren Illinois appealed to the Appellate Court of the Fourth District of Illinois. In December 2012, the ICC issued an order in Ameren Illinois’ update filing approving an Ameren Illinois electric delivery service revenue requirement of $765 million, based on 2011 recoverable costs and expected net plant additions in 2012. The delivery service rates became effective on January 1, 2013. In January 2013, Ameren Illinois filed an appeal of the ICC’s update filing order to the Appellate Court of the Fourth District of Illinois. Both orders were consolidated for appeal with the primary issues being the treatment of accumulated deferred income taxes and vacation obligations as well as the calculation of Ameren Illinois’ capital structure. In December 2013, the appellate court rendered its decision upholding the ICC’s September and December 2012 orders. Ameren Illinois expects to file an appeal to the Illinois Supreme Court in March 2014. In December 2013, the ICC issued an order in Ameren Illinois’ annual update filing, which was based on 2012 recoverable costs and expected net plant additions for 2013, approving an Ameren Illinois electric delivery service revenue requirement of $788 million, before consideration of the 2012 revenue requirement reconciliation refund. The ICC order resulted in a net $45 million decrease in Ameren Illinois’ electric delivery service revenue requirement. The calculation included a refund to customers of the 2012 revenue requirement reconciliation of $68 million, which included an estimate for interest through the end of 2014. However, this refund is partially offset by an annual revenue requirement increase of $23 million primarily due to higher recoverable costs in 2012 compared to 2011. The ICC order establishes rates for all of 2014. In January 2014, Ameren Illinois filed a request for rehearing with the ICC regarding the electric delivery service rate order, which the ICC denied. In February 2014, Ameren Illinois filed an appeal with the Appellate Court of the Fourth District of Illinois regarding the calculation of its capital structure and the treatment of accumulated deferred income taxes related to the transfer of former Ameren Missouri assets in Illinois to Ameren Illinois. In the December 2013 order, the ICC disallowed, in part, the recovery from customers of the debt premium costs paid by Ameren Illinois for a tender offer in August 2012 to repurchase outstanding senior secured notes. At the time of the tender offer, Ameren Illinois recorded this loss on the reacquired debt as a regulatory asset. As a result of the ICC order, Ameren and Ameren Illinois each recorded in 2013 a pretax charge to earnings of $15 million relating to the partial disallowance of the premium costs. This charge was recorded in the statement of income for Ameren and Ameren Illinois as “Interest charges” with a corresponding decrease to “Regulatory assets.” 2013 Natural Gas Delivery Service Rate Order In December 2013, the ICC issued a rate order that approved an increase in revenues for natural gas delivery service of $32 million. The revenue increase was based on a 9.1% return on equity, a capital structure composed of 51.7% common equity, and a rate base of $1.1 billion. The rate order was based on a 2014 future test year. The rate changes became effective January 1, 2014. In January 2014, Ameren Illinois filed a request for rehearing with the ICC regarding the natural gas delivery service rate order, which the ICC denied. Ameren Illinois expects to file an appeal of the ICC’s order in March 2014. Similar to the December 2013 electric rate order discussed above, this natural gas rate order included a partial disallowance relating to the August 2012 costs for the tender offer to repurchase outstanding senior secured notes. The pretax loss of $15 million discussed above includes the impact of both the December 2013 ICC electric and natural gas delivery service rate orders. Natural Gas Consumer, Safety and Reliability Act In July 2013, Illinois enacted the Natural Gas Consumer, Safety and Reliability Act, which encourages Illinois natural gas utilities to accelerate modernization of the state’s natural gas infrastructure and provides additional ICC oversight of natural gas utility performance. The law allows natural gas utilities the option to file for, and requires the ICC to approve, a rate rider mechanism to recover costs of certain natural gas infrastructure investments made between rate cases. The law does not require a minimum level of investment. Ameren Illinois expects to begin including investments under this regulatory framework in 2015. Ameren Illinois’ decision to accelerate modernization of its natural gas infrastructure under this regulatory framework is dependent upon multiple considerations, including the allowed return on equity under this framework compared with other Ameren and Ameren Illinois investment options. ATXI Transmission Project ATXI’s Illinois Rivers project is a MISO-approved project to build a 345-kilovolt line from western Indiana across the state of Illinois to eastern Missouri at an estimated cost of $1.1 billion. In August 2013, the ICC granted a certificate of public convenience and necessity and approved seven of a total of nine sections of the route and three of the proposed nine substations for the Illinois Rivers project. The ICC order indicated the project is necessary to address transmission and reliability needs in an efficient and equitable manner and that the project will benefit the development of a competitive electricity market. The order also indicated that ATXI is capable of constructing, managing and financing the project. In 94 October 2013, the ICC granted ATXI’s request for a rehearing to consider additional evidence regarding the two segments of the route and six substations that were not approved, as well as the requests for rehearing of certain other parties regarding two of the approved segments of the route. In February 2014, the ICC issued a final order on rehearing approving the remaining substations and routes for the Illinois Rivers project. Federal 2011 Wholesale Distribution Rate Case In January 2011, Ameren Illinois filed a request with FERC to increase its annual revenues for electric delivery service for its wholesale customers. These wholesale distribution revenues are treated as a deduction from Ameren Illinois’ revenue requirement in retail rate filings with the ICC. In March 2011, FERC issued an order authorizing the proposed rates to take effect, subject to refund when the final rates are determined. Ameren Illinois reached an agreement with four of its nine wholesale customers. FERC has approved these settlement agreements, and any refund obligations related thereto have been made. The impasse with the remaining five wholesale customers has resulted in FERC litigation. In November 2012, a FERC administrative law judge issued an initial decision, which is now pending before FERC. The timing of a FERC decision is uncertain. In accordance with the administrative law judge’s initial decision, Ameren and Ameren Illinois have both included on their balance sheets in “Current regulatory liabilities” an estimate of $13 million and $8 million as of December 31, 2013, and December 31, 2012, respectively, for the refund due to wholesale customers relating to billings for the period from March 2011 through December 2013. Ameren Illinois Electric Transmission Rate Refund In July 2012, FERC issued an order concluding that Ameren Illinois improperly included acquisition premiums, primarily goodwill, in determining the common equity used in its electric transmission formula rate, and thereby inappropriately recovered a higher amount from its electric transmission customers. The order required Ameren Illinois to make refunds to customers for such improperly included amounts. In August 2012, Ameren Illinois filed a request for a rehearing of this order. It is unknown when FERC will rule on Ameren’s rehearing request, as it is under no deadline to do so. Ameren Illinois submitted a refund report in November 2012 and concluded that no refund was warranted. Several wholesale customers filed a protest with FERC regarding Ameren’s conclusion that no refund was warranted. In June 2013, FERC issued an order that rejected Ameren Illinois’ November 2012 refund report and provided guidance as to the filing of a new refund report. In July 2013, Ameren Illinois filed a revised refund report based on the guidance provided in the June 2013 order, as well as a request for a rehearing of that order. Ameren Illinois’ July 2013 refund report also concluded that no refund was warranted. Ameren Illinois estimated the maximum pretax charge to earnings for this possible refund obligation through December 31, 2013, would be $15 million, before interest charges. If Ameren Illinois were to determine that a refund to its electric transmission customers is probable, a charge to earnings would be recorded for the refund in the period in which that determination was made. FERC Complaint Case In November 2013, a customer group filed a complaint case with FERC seeking a reduction in the allowed return on common equity, as well as a limit on the common equity ratio, under the MISO tariff. Currently, the FERC-allowed return on common equity for MISO transmission owners is 12.38%. This complaint case could result in a reduction to Ameren Illinois’ and ATXI’s allowed return on common equity. That reduction could also result in a refund for transmission service revenues earned after the filing of the complaint case in November 2013. FERC has not issued an order in this case, and it is under no deadline to do so. Ameren is not able to predict when or how FERC will rule on this complaint case. Ameren Missouri Power Purchase Agreement with Entergy Beginning in 2005, FERC issued a series of orders addressing a complaint filed in 2001 by the Louisiana Public Service Commission (LPSC) against Entergy and certain of its affiliates. The complaint alleged unjust and unreasonable cost allocations. As a result of the FERC orders, Entergy began billing Ameren Missouri in 2007 for additional charges under a 165-megawatt power purchase agreement, which expired August 31, 2009. In May 2012, FERC issued an order stating that Entergy should not have included additional charges to Ameren Missouri under the power purchase agreement. Pursuant to the order, in June 2012, Entergy paid Ameren Missouri $31 million, with $24 million recorded as a reduction to “Purchased power” expense and $5 million for interest recorded as “Miscellaneous income” in the statement of income. The remaining $2 million was recorded as an offset to the FAC under-recovered regulatory asset for the amount refundable to customers. The amount of the Entergy refund recorded to the FAC regulatory asset related to the period when the FAC was effective; therefore, such costs were previously included in customer rates. In July 2012, Entergy filed an appeal of FERC’s January 2010 and May 2012 orders to the United States Court of Appeals for the District of Columbia Circuit, which was subsequently dismissed on a procedural issue. In November 2013, Entergy refiled the appeal of FERC’s May 2012 order with the United States Court of Appeals for the District of Columbia Circuit. Ameren is not able to predict when or how the court will rule on Entergy’s appeal. The LPSC appealed FERC’s orders regarding LPSC’s complaint against Entergy Services, Inc. to the United States Court of Appeals for the District of Columbia Circuit. In April 2008, that court ordered further FERC proceedings regarding LPSC’s complaint. The court ordered FERC to explain its previous denial of retroactive refunds and the implementation of prospective charges. FERC’s decision on 95 remand of the retroactive impact of these issues could have a financial impact on Ameren Missouri. Ameren Missouri is unable to predict when or how FERC will respond to the court’s decisions. Ameren Missouri estimates that it could incur an additional expense of up to $25 million if FERC orders retroactive application for the years 2001 to 2005. Ameren Missouri believes that the likelihood of incurring any expense is not probable, and therefore no liability has been recorded as of December 31, 2013. Combined Construction and Operating License In 2008, Ameren Missouri filed an application with the NRC for a COL for a new nuclear unit at Ameren Missouri’s existing Callaway County, Missouri, energy center site. In 2009, Ameren Missouri suspended its efforts to build a new nuclear unit at its existing Missouri nuclear energy center site, and the NRC suspended review of the COL application. In March 2012, the DOE announced the availability of investment funds for the design, engineering, manufacturing, and sale of American-made small modular nuclear reactors. In April 2012, Ameren Missouri entered into an exclusive agreement to support Westinghouse’s application for the first installment of DOE’s small modular nuclear reactor investment funds. The DOE investment funding is intended to support engineering and design certifications and a COL for up to two small modular reactor designs over five years. A COL is issued by the NRC to permit construction and operation of a nuclear energy center at a specific site in accordance with established laws and regulations. Obtaining a COL from the NRC would not obligate Ameren Missouri to build a small modular reactor at the Callaway site; however, it would preserve the option to move forward in a timely fashion should conditions be right to build a small modular reactor in the future. A COL is valid for at least 40 years. In November 2012, the DOE awarded the first installment of investment funds for only one small modular reactor design, which was not the Westinghouse design. The DOE stated that a second installment of investment funds would be awarded during 2013. In December 2013, the DOE did not award Westinghouse the second installment of investment funds. Ameren Missouri’s agreement to exclusively support Westinghouse’s application expired in January 2014. Ameren Missouri estimated the total cost that would be required to obtain the small modular reactor COL to be $80 million to $100 million. As of December 31, 2013, Ameren Missouri had capitalized investments of $69 million for the development of a new nuclear energy center. Ameren is currently evaluating all potential nuclear technologies in order to maintain an option for nuclear power in the future. All of Ameren Missouri’s capitalized investments for the development of a new nuclear energy center will remain capitalized while management pursues options to maximize the value of its investment. If efforts to license additional nuclear generation are abandoned or management concludes it is probable the costs incurred will be disallowed in rates, a charge to earnings would be recognized in the period in which that determination is made. Pumped-storage Hydroelectric Energy Center Relicensing In June 2008, Ameren Missouri filed a relicensing application with FERC to operate its Taum Sauk pumped- storage hydroelectric energy center for another 40 years. The existing FERC license expired on June 30, 2010. In July 2010, Ameren Missouri received a license extension that allows Taum Sauk to continue operations until FERC issues a new license. A FERC order is expected in 2014. Ameren Missouri cannot predict the ultimate outcome of FERC’s review of the application. 96 Regulatory Assets and Liabilities In accordance with authoritative accounting guidance regarding accounting for the effects of certain types of regulation, Ameren Missouri and Ameren Illinois defer certain costs as regulatory assets pursuant to actions of regulators or based on the expected ability to recover such costs in rates charged to customers. Ameren Missouri and Ameren Illinois also defer certain amounts as regulatory liabilities because of actions of regulators or because of the expectation that such amounts will be returned to customers in future rates. The following table presents Ameren’s, Ameren Missouri’s and Ameren Illinois’ regulatory assets and regulatory liabilities at December 31, 2013, and 2012: Ameren Missouri 2013 Ameren Illinois Ameren Ameren Missouri 2012 Ameren Illinois Ameren $ $ $ $ $ $ $ Current regulatory assets: Under-recovered FAC(a)(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Under-recovered Illinois electric power costs(c) . . . . . . . . . . . . . . Under-recovered PGA(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MTM derivative losses(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncurrent regulatory assets: Pension and postretirement benefit costs(e) . . . . . . . . . . . . . . . . . Income taxes(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Asset retirement obligations(g) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Callaway costs(a)(h) Unamortized loss on reacquired debt(a)(i) . . . . . . . . . . . . . . . . . . . Recoverable costs – contaminated facilities(j) . . . . . . . . . . . . . . . . MTM derivative losses(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Storm costs(k) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Demand-side costs before MEEIA implementation(a)(l) Reserve for workers’ compensation liabilities(m) . . . . . . . . . . . . . Credit facilities fees(n) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Common stock issuance costs(o) Construction accounting for pollution control equipment(a)(p) . . . Solar rebate program(a)(q) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IEIMA revenue requirement reconciliation(r) . . . . . . . . . . . . . . . . . Other(s)(t) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total noncurrent regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . Current regulatory liabilities: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Over-recovered FAC(b) . . . . . . . . . . . . . . . Over-recovered Illinois electric power costs(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Over-recovered PGA(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MTM derivative gains(d) Wholesale distribution refund(u) . . . . . . . . . . . . . . . . . . . . . . . . . . IEIMA revenue requirement reconciliation(r) . . . . . . . . . . . . . . . . . Total current regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncurrent regulatory liabilities: Income taxes(v) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Removal costs(w) Asset retirement obligation(g) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MTM derivative gains(d) Bad debt riders(x) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and postretirement benefit costs tracker(y) Energy efficiency riders(z) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IEIMA revenue requirement reconciliation(r) . . . . . . . . . . . . . . . . . FERC transmission revenue requirement reconciliation(aa) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(ab) $ $ $ $ $ $ $ 104 - - 14 118 44 230 - 40 77 - 8 5 58 6 5 4 22 27 - 8 534 26 - 5 26 - - 57 38 828 146 1 - 15 3 - - 10 Total noncurrent regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . $ 1,041 $ - 1 1 36 38 140 7 5 - 74 271 118 3 - 6 - - - - 65 12 701 - 51 29 1 13 65 159 3 610 - - 8 - 33 - 10 - 664 $ $ $ $ $ $ $ $ $ $ $ $ $ $ 104 1 1 50 156 184 237 5 40 151 271 126 8 58 12 5 4 22 27 65 25 1,240 26 51 34 27 13 65 216 41 1,438 146 1 8 15 36 - 10 10 $ 1,705 $ 145 - 5 13 163 348 231 - 44 81 - 7 9 73 6 6 7 23 5 - 12 852 - - - 18 - - 18 42 766 80 2 - 23 - - - 4 917 $ $ $ $ $ $ $ $ - - 7 77 84 424 4 5 - 100 248 128 - - 6 - - - - - 19 934 - 58 15 1 8 - 82 4 581 - - 12 - 20 55 - - 672 $ $ $ $ $ $ $ 145 - 12 90 247 772 235 5 44 181 248 135 9 73 12 6 7 23 5 - 31 1,786 - 58 15 19 8 - 100 46 1,347 80 2 12 23 20 55 - 4 $ 1,589 (a) These assets earn a return. (b) Under-recovered or over-recovered fuel costs to be recovered 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 customers that occurs over the next eight months. (c) Costs under- or over-recovered from utility customers. Amounts will be recovered from, or refunded to, customers within one year of the deferral. (d) Deferral of commodity-related derivative MTM losses or gains. See Note 7 – Derivative Financial Instruments for additional information. 97 (e) These costs are being amortized in proportion to the recognition of prior service costs (credits), transition obligations (assets), and actuarial losses (gains) attributable to Ameren’s pension plan and postretirement benefit plans. See Note 11 – Retirement Benefits for additional information. (f) Offset to certain deferred tax liabilities for expected recovery of future income taxes when paid. This will be recovered over the expected life of the related assets. (g) Recoverable or refundable removal costs for AROs, including net realized and unrealized gains and losses related to the nuclear decommissioning trust fund investments. See Note 1 – Summary of Significant Accounting Policies – Asset Retirement Obligations. (h) Ameren Missouri’s Callaway energy center operations and maintenance expenses, property taxes, and carrying costs incurred between the (i) (j) plant in-service date and the date the plant was reflected in rates. These costs are being amortized over the remaining life of the energy center’s current operating license, which expires in 2024. 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 15 – Commitments and Contingencies for additional information. (k) Actual storm costs in a test year that exceed the MoPSC staff’s normalized storm costs for rate purposes. As approved by the December 2012 MoPSC electric rate order, the 2006, 2007, and 2008 storm costs are being amortized through December 2014. As approved by the May 2010 MoPSC electric rate order, the 2009 storm costs are being amortized through June 2015. The Ameren Illinois total includes 2013 storm costs deferred in accordance with the IEIMA. These costs are being amortized over a five-year period beginning in 2013. (l) Demand-side costs incurred prior to implementation of the MEEIA in 2013, including the costs of developing, implementing and evaluating customer energy efficiency and demand response programs. Costs incurred from May 2008 through September 2008 are being amortized over a 10-year period that began in March 2009. Costs incurred from October 2008 through December 2009 are being amortized over a six-year period that began in July 2010. Costs incurred from January 2010 through February 2011 are being amortized over a six-year period that began in August 2011. Costs incurred from March 2011 through July 2012 are being amortized over a six-year period that began in January 2013. (m) Reserve for workers’ compensation claims. The period of recovery will depend on the timing of actual expenditures. (n) Ameren Missouri’s costs incurred to enter into and maintain the 2012 Ameren Missouri Credit Agreement. These costs are being amortized over five years, beginning in November 2012. These costs are being amortized to construction work in progress, which will be depreciated when assets are placed into service. (o) The MoPSC’s May 2010 electric rate order allowed Ameren Missouri to recover its portion of Ameren’s September 2009 common stock issuance costs. These costs are being amortized over five years, beginning in July 2010. (p) 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 could be included in customer rates. These costs will be amortized over the expected life of the Sioux energy center, which is currently through 2033. (q) Costs associated with Ameren Missouri’s solar rebate program beginning in August 2012 to fulfill Ameren Missouri’s renewable energy (r) portfolio requirement. The amortization period for these costs will be three years, commencing with the next Ameren Missouri electric rate case order. The asset balance relates to the difference between Ameren Illinois’ 2013 revenue requirement calculated under the IEIMA’s performance-based formula ratemaking framework, and the revenue requirement included in customer rates for 2013. Subject to ICC approval, this asset will be collected from customers in 2015. The liability balance relates to the difference between Ameren Illinois’ 2012 revenue requirement calculated under the IEIMA’s performance-based formula ratemaking framework and the revenue requirement included in customer rates for 2012. This liability will be refunded to customers in 2014. (s) The Ameren Illinois total includes Ameren Illinois Merger integration and optimization costs, which are amortized over four years, beginning in January 2012. The Ameren Illinois total also includes costs related to the 2013 natural gas delivery service rate case costs, which are being amortized over a two-year period that began in January 2014. The Ameren Illinois total also includes a portion of the unamortized debt fair value adjustment recorded upon Ameren’s acquisition of IP. This portion is being amortized over the remaining life of the related debt. At Ameren Missouri, the balance primarily includes the cost of renewable energy credits to fulfill its renewable energy portfolio requirement. Costs incurred from January 2010 through July 2012 are being amortized over three years, beginning in January 2013. The Ameren total includes $5 million for ATXI’s revenue requirement reconciliation adjustments for 2012 and 2013 calculated pursuant to the FERC’s electric transmission formula ratemaking framework. These adjustments will be collected from customers in 2014 for the 2012 revenue requirement reconciliation and in 2015 for the 2013 revenue requirement reconciliation. (t) (u) Estimated refund to wholesale electric customers. See 2011 Wholesale Distribution Rate Case above. (v) Unamortized portion of investment tax credits, federal excess deferred taxes, and uncertain tax position tracker. The tracker is being amortized over three years, beginning in January 2013. The unamortized portion of investment tax credit is being amortized over the expected life of the underlying assets. (w) Estimated funds collected for the eventual dismantling and removal of plant from service, net of salvage value, upon retirement related to our rate-regulated operations. (x) A regulatory tracking mechanism for the difference between the level of bad debt expense incurred by Ameren Illinois under GAAP and the level of such costs included in electric and natural gas rates. The over-recovery relating to 2011 was refunded to customers from June 2012 through May 2013. The over-recovery relating to 2012 is being refunded to customers from June 2013 through May 2014. The over-recovery relating to 2013 will be refunded to customers from June 2013 through May 2014. (y) A regulatory tracking mechanism for the difference between the level of pension and postretirement benefit costs incurred by Ameren Missouri under GAAP and the level of such costs built into rates. For periods prior to August 2012, the MoPSC’s December 2012 electric rate order directed the amortization to occur over five years, beginning in January 2013. For periods after August 2012, the amortization period will be determined in a future Ameren Missouri electric rate case. (z) The Ameren Illinois balance relates its regulatory tracking mechanism to recover its electric and natural gas costs associated with developing, implementing, and evaluating customer energy efficiency and demand response programs. This over-recovery will be refunded to customers 98 over the following 12 months after the plan year. The Ameren Missouri balance relates to its MEEIA program costs incurred and projected lost revenues compared to the amount previously collected from customers. Beginning in January 2014, a MEEIA rider allows Ameren Missouri to collect from or refund to customers any annual difference in the actual amounts incurred and the projected amounts collected from customers for the MEEIA program costs and its projected lost revenues. Under the MEEIA rider, collections from or refunds to customers occur one year after the program costs and projected lost revenues are incurred. (aa) Ameren Illinois’ 2013 revenue requirement reconciliation adjustment calculated pursuant to the FERC’s electric transmission formula ratemaking framework. This liability will be refunded to customers in 2015. (bb) Balance primarily includes the costs of renewable energy credits to fulfill Ameren Missouri’s renewable energy portfolio requirement from August 2012 through December 2013, which were less than the amount included in rates. The amortization period for this over-recovery will be determined in a future Ameren Missouri electric rate case. Ameren Missouri and Ameren Illinois continually assess the recoverability of their regulatory assets. Under current accounting standards, 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 payments of regulatory liabilities are no longer probable, the amounts are credited to earnings. NOTE 3 – PROPERTY AND PLANT, NET The following table presents property and plant, net, for each of the Ameren Companies at December 31, 2013, and 2012: Ameren Missouri(a) Ameren Illinois Other Ameren(a)(b) 2013 Property and plant, at original cost: Electric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Less: Accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Construction work in progress: Nuclear fuel in process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15,964 413 16,377 6,766 9,611 246 595 $ 5,426 1,562 6,988 1,627 5,361 - 228 $ 336 - 336 251 85 - 79 $ 21,726 1,975 23,701 8,644 15,057 246 902 Property and plant, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 10,452 $ 5,589 $ 164 $ 16,205 2012 Property and plant, at original cost: Electric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Less: Accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Construction work in progress: Nuclear fuel in process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15,638 393 16,031 6,614 9,417 317 427 $ 4,985 1,461 6,446 1,495 4,951 - 101 $ 319 - 319 237 82 - 53 $ 20,942 1,854 22,796 8,346 14,450 317 581 Property and plant, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 10,161 $ 5,052 $ 135 $ 15,348 (a) Amounts in Ameren and Ameren Missouri include two electric generation CTs under separate capital lease agreements. The gross cumulative asset value of those agreements was $228 million at December 31, 2013, and $228 million at December 31, 2012. The total accumulated depreciation associated with the two CTs was $56 million and $52 million at December 31, 2013, and 2012, respectively. In addition, Ameren Missouri has investments in debt securities, which were classified as held-to-maturity, related to the two CTs from the city of Bowling Green and Audrain County. As of December 31, 2013, and 2012, the carrying value of these debt securities was $299 million and $304 million, respectively. Includes amounts for Ameren registrant and nonregistrant subsidiaries. (b) 99 The following table provides accrued capital and nuclear fuel expenditures at December 31, 2013, 2012, and 2011, which represent noncash investing activity excluded from the accompanying statements of cash flows: Accrued capital expenditures: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Accrued nuclear fuel expenditures: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 175 107 97 8 8 36 $ 74 63 73 8 8 36 $ 86 37 18 (b) (b) (b) Ameren(a) Ameren Missouri Ameren Illinois Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) Not applicable. NOTE 4 – SHORT-TERM DEBT AND LIQUIDITY The liquidity needs of the Ameren Companies are typically supported through the use of available cash, short-term intercompany borrowings, drawings under committed bank credit agreements, or commercial paper issuances. 2012 Credit Agreements On November 14, 2012, Ameren and Ameren Missouri entered into the $1 billion 2012 Missouri Credit Agreement. The 2010 Missouri Credit Agreement was terminated when the 2012 Missouri Credit Agreement when into effect. Also on November 14, 2012, Ameren and Ameren Illinois entered into the $1.1 billion 2012 Illinois Credit Agreement. The 2010 Illinois Credit Agreement was terminated when the 2012 Illinois Credit Agreement went into effect. These facilities cumulatively provide $2.1 billion of credit through November 14, 2017, which may be extended with the agreement of the lenders, subject to the terms of such agreements, for two additional one-year periods. The facilities currently include 24 international, national, and regional lenders, with no lender providing more than $125 million of credit in aggregate. The obligations of each borrower under the respective 2012 Credit Agreements to which it is a party are several and not joint, and, except under limited circumstances relating to expenses and indemnities, the obligations of Ameren Missouri and Ameren Illinois under the respective 2012 Credit Agreements are not guaranteed by Ameren or any other subsidiary of Ameren. The maximum aggregate amount available to each borrower under each facility is shown in the following table (such amount being such borrower’s “Borrowing Sublimit”): Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 500 800 (a) $ 300 (a) 800 2012 Missouri Credit Agreement 2012 Illinois Credit Agreement (a) Not applicable. Ameren has the option to seek additional commitments from existing or new lenders to increase the total facility size of the 2012 Credit Agreements up to a maximum amount of $1.2 billion for the 2012 Missouri Credit Agreement and $1.3 billion for the 2012 Illinois Credit Agreement. The 2012 Credit Agreements as well as the Borrowing Sublimits of Ameren and Ameren Missouri, will mature and expire on November 14, 2017. The Borrowing Sublimit of Ameren Illinois will mature and expire on September 30, 2014, subject to extension on a 364-day basis or for a longer period upon notice by the borrower of receipt of any and all required federal or state regulatory approvals, as permitted under the credit agreement, but in no event later than November 14, 2017. In October 2013, Ameren Illinois filed a petition seeking state regulatory approval necessary to extend the maturity date of its Borrowing Sublimit under the 2012 Illinois Credit Agreement to November 14, 2017. If and when regulatory approval is received, no lender approval will be required to effect the extension. The principal amount of each revolving loan owed by a borrower under any of the 2012 Credit Agreements to which it is a party will be due and payable no later than the final maturity date relating to such borrower under such 2012 Credit Agreements. The obligations of all borrowers under the 2012 Credit Agreements are unsecured. Loans are available on a revolving basis under each of the 2012 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 (“ABR”) plus the margin applicable to the particular borrower and/or the 100 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 then in effect, the borrower’s corporate/issuer ratings then in effect. Letters of credit in an aggregate undrawn face amount not to exceed 25% of the applicable aggregate commitment under the respective 2012 Credit Agreements are also available for issuance for the account of the borrowers thereunder (but within the $2.1 billion overall combined facility borrowing limitations of the 2012 Credit Agreements). The borrowers will use the proceeds from any borrowings under the 2012 Credit Agreements for general corporate purposes, including working capital, commercial paper liquidity support, loan funding under the Ameren money pool arrangements or other short-term intercompany loan arrangements, or paying fees and expenses incurred in connection with the 2012 Credit Agreements. Commercial Paper The 2012 Credit Agreements are used to borrow cash, to issue letters of credit, and to support issuances under Ameren’s $500 million commercial paper program and Ameren Missouri’s $500 million commercial paper program. Either of the 2012 Credit Agreements are available to Ameren to support issuances under Ameren’s commercial paper program, subject to borrowing sublimits. The 2012 Missouri Credit Agreement is available to support issuances under Ameren Missouri’s commercial paper program. Ameren Illinois’ $500 million commercial paper program, under which no commercial paper was ever issued, was terminated in 2013. As of December 31, 2013, based on commercial paper outstanding and letters of credit issued under the 2012 Credit Agreements, the aggregate amount of credit capacity available to Ameren (parent), Ameren Missouri and Ameren Illinois, collectively, at December 31, 2013, was $1.7 billion. Ameren, Ameren Missouri, and Ameren Illinois did not borrow under the 2012 Credit Agreements for the years ended December 31, 2013, and 2012. The following table summarizes the borrowing activity and relevant interest rates under Ameren’s commercial paper program, for the years ended December 31, 2013, and 2012: Average daily borrowings outstanding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Outstanding borrowings at period-end . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Weighted-average interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Peak borrowings during period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Peak interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2013 2012 $ $ 54 368 0.56% 368 0.85% $ $ 49 - 0.92% 229 1.25% Indebtedness Provisions and Other Covenants The information below presents a summary of the Ameren Companies’ compliance with indebtedness provisions and other covenants. The 2012 Credit Agreements contain conditions to borrowings and issuances of letters of credit, including 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, as it relates to borrowings under the 2012 Illinois Credit Agreement, it is a condition for any such borrowing that, at the time of and after giving effect to such borrowing, the borrower not be in violation of any limitation on its ability to incur unsecured indebtedness contained in its articles of incorporation. The 2012 Credit Agreements also contain nonfinancial covenants, including restrictions on the ability to incur 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 2012 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, 2013, the ratios of consolidated indebtedness to total consolidated capitalization, calculated in accordance with the provisions of the 2012 Credit Agreements, were 48%, 47% and 44%, for Ameren, Ameren Missouri and Ameren Illinois, respectively. In addition, under the 2012 Illinois Credit Agreement and, by virtue of the cross-default provisions of the 2012 Missouri Credit Agreement, Ameren is required to maintain a ratio of consolidated funds from operations plus interest expense to consolidated interest expense of 2.0 to 1.0, to be calculated quarterly, as of the end of the most recent four fiscal quarters then ending, in accordance with the 2012 Illinois Credit Agreement. Ameren’s ratio as of December 31, 2013, was 5.3 to 1.0. Failure of a borrower to satisfy a financial covenant constitutes an immediate default under the applicable 2012 Credit Agreement. The 2012 Credit Agreements contain default provisions that apply separately to each borrower, provided, however, that a default of Ameren Missouri or Ameren Illinois under the applicable 2012 Credit Agreement will also be deemed to constitute a default of Ameren under such agreement. 101 Defaults include a cross-default to 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 $50 million in the aggregate (including under the other 2012 Credit Agreement). However, under the default provisions of the 2012 Credit Agreements, any default of Ameren under any such 2012 Credit Agreements that results solely from a default of Ameren Missouri or Ameren Illinois thereunder does not result in a cross-default of Ameren under the other 2012 Credit Agreement. Further, the 2012 Credit Agreement default provisions provide that an Ameren default under any of the 2012 Credit Agreements does not trigger a default by Ameren Missouri or Ameren Illinois. None of the Ameren Companies’ credit agreements or financing arrangements contain credit rating triggers that would cause a default or acceleration of repayment of outstanding balances. Management believes that the Ameren Companies were in compliance with the provisions and covenants of their credit agreements at December 31, 2013. primary sources of external funds for the money pool are the 2012 Credit Agreements and the commercial paper programs. The total amount available to the pool participants from the 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 money pool or remit funds from other external sources. The availability of funds is also determined by funding requirement limits established by regulatory authorizations. The money pool was established to coordinate and to provide short-term cash and working capital for the participants. Participants receiving a loan under the 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 money pool. The average interest rate for borrowing under the money pool for the year ended December 31, 2013, was 0.14% (2012 – 0.13%). See Note 14 – Related Party Transactions for the amount of interest income and expense from the money pool arrangements recorded by the Ameren Companies for the years ended December 31, 2013, 2012, and 2011. Money Pools Unilateral Borrowing Agreement Ameren has money pool agreements with and among its subsidiaries to coordinate and provide for certain short- term cash and working capital requirements. Ameren Services is responsible for the operation and administration of the money pool agreements. Ameren Missouri, Ameren Illinois, and Ameren Services may participate in the utility money pool as both lenders and borrowers. Ameren may participate in the money pool only as a lender. Internal funds are surplus funds contributed to the money pool from participants. The In addition, a unilateral borrowing agreement exists among Ameren, Ameren Illinois, and Ameren Services, which enables Ameren Illinois to make short-term borrowings directly from Ameren. The aggregate amount of borrowings outstanding at any time by Ameren Illinois under the unilateral borrowing agreement and the utility money pool agreement, together with any outstanding Ameren Illinois external credit facility borrowings, may not exceed $500 million, pursuant to authorization from the ICC. Ameren Illinois is not currently borrowing under the unilateral borrowing agreement. 102 NOTE 5 – LONG-TERM DEBT AND EQUITY FINANCINGS The following table presents long-term debt outstanding, including maturities due within one year, for the Ameren Companies as of December 31, 2013, and 2012: Ameren (Parent): 8.875% Senior unsecured notes due 2014 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 425 $ 425 Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year - (425) (1) - Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ - $ 424 2013 2012 Ameren Missouri: Senior secured notes:(a) 4.65% Senior secured notes due 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.50% Senior secured notes due 2014 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.75% Senior secured notes due 2015 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.40% Senior secured notes due 2016 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.40% Senior secured notes due 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.00% Senior secured notes due 2018(b) 5.10% Senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.70% Senior secured notes due 2019(b) 5.10% Senior secured notes due 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.00% Senior secured notes due 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.50% Senior secured notes due 2034 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.30% Senior secured notes due 2037 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.45% Senior secured notes due 2039(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.90% Senior secured notes due 2042(b) Environmental improvement and pollution control revenue bonds: 1992 Series due 2022(c)(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 5.45% Series due 2028(e) 1998 Series A due 2033(c)(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1998 Series B due 2033(c)(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1998 Series C due 2033(c)(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Capital lease obligations: City of Bowling Green capital lease (Peno Creek CT) through 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Audrain County capital lease (Audrain County CT) due 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - 104 114 260 425 179 199 329 244 85 184 300 350 485 47 (e) 60 50 50 59 240 Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,764 Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year (7) (109) 200 104 114 260 425 179 199 329 244 85 184 300 350 485 47 44 60 50 50 64 240 4,013 (7) (205) Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,648 $3,801 103 2013 2012 Ameren Illinois: Senior secured notes: 8.875% Senior secured notes due 2013(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.20% Senior secured notes due 2016(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.25% Senior secured notes due 2016(g) 6.125% Senior secured notes due 2017(g)(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.25% Senior secured notes due 2018(g)(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.75% Senior secured notes due 2018(g)(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.70% Senior secured notes due 2022(g)(h) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.125% Senior secured notes due 2028(g) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.70% Senior secured notes due 2036(g) 6.70% Senior secured notes due 2036(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.80% Senior secured notes due 2043(g) $ Environmental improvement and pollution control revenue bonds: 5.90% Series 1993 due 2023(i) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.70% 1994A Series due 2024(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 Series C-1 5.95% due 2026(k) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 Series C-2 5.70% due 2026(k) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 Series B-1 due 2028(d)(k) 5.40% 1998A Series due 2028(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.40% 1998B Series due 2028(j) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair-market value adjustments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - 54 75 250 144 313 400 60 61 42 280 32 36 35 8 17 19 33 4 Total long-term debt, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,863 Less: Unamortized discount and premium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Maturities due within one year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (7) - $ 150 54 75 250 144 313 400 60 61 42 - 32 36 35 8 17 19 33 4 1,733 (6) (150) Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren consolidated long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 1,856 5,504 $ $ 1,577 5,802 (a) 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 Ameren Missouri first mortgage bonds and senior secured notes currently outstanding, and assuming no early retirement of any series of such securities in full, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2042. (b) Ameren Missouri has agreed, during the life of these notes, not to optionally redeem, purchase or otherwise retire in full its first mortgage bonds. Ameren Missouri has also agreed to prevent a first mortgage bond release date from occurring as long as any of the 8.45% senior secured notes due 2039 and any of the 3.90% senior secured notes due 2042 remain outstanding. (c) 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. The bonds are also backed by an insurance guarantee policy. Interest rates, and periods during which such rates apply, vary depending on our selection of defined rate modes. Maximum interest rates could range up to 18% depending on the series of bonds. The average interest rates for 2013 and 2012 were as follows: (d) Ameren Missouri 1992 Series . . . . . . . . . . Ameren Missouri 1998 Series A . . . . . . . . Ameren Missouri 1998 Series B . . . . . . . . Ameren Missouri 1998 Series C . . . . . . . . Ameren Illinois 1993 Series B-1 . . . . . . . . 2013 2012 0.17% 0.30% 0.34% 0.65% 0.33% 0.64% 0.34% 0.64% 0.14% 0.22% (e) These bonds are first mortgage bonds issued by Ameren Missouri under the Ameren Missouri mortgage bond indenture and are secured by (f) substantially all Ameren Missouri property and franchises. The bonds are callable at 100% of par value. Less than $1 million principal amount of the bonds remain outstanding. These notes are collaterally secured by first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture. The notes have a fall-away lien provision and will remain secured only as long as any series of first mortgage bonds issued under the CILCO 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 CILCO first mortgage bonds and senior secured notes currently outstanding, and assuming no early retirement of any series of such securities in full, we do not expect the first mortgage bond lien protection associated with these notes to fall away until 2023. (g) These notes are collaterally secured by 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 series of first mortgage bonds issued under the Ameren Illinois mortgage indenture remain outstanding. Redemption, purchase, or maturity of all mortgage bonds, including first mortgage bonds currently 104 outstanding and any that may be issued in the future, would result in a release of the mortgage bonds currently securing these notes, at which time these notes would become unsecured obligations. Considering the Ameren Illinois mortgage bonds and senior secured notes currently outstanding, and assuming no early retirement of any series of such securities in full, we do not expect the mortgage bond lien protection associated with these notes to fall away until 2028. (h) Ameren Illinois has agreed, during the life of these notes, not to optionally redeem, purchase, or otherwise retire in full its Ameren Illinois (i) (j) mortgage bonds; therefore, an Ameren Illinois first mortgage bond release date will not occur as long as any of these notes are outstanding. These bonds are first mortgage bonds issued by Ameren Illinois under the CILCO mortgage indenture and are secured by substantially all property of the former CILCO. The bonds are callable at 100% of par value. These bonds are mortgage bonds issued by Ameren Illinois under the Ameren Illinois mortgage indenture and are secured by substantially all property of the former IP and CIPS. The bonds are callable at 100% of par value. The bonds are also backed by an insurance guarantee policy. (k) The bonds are callable at 100% of par value. The following table presents the aggregate maturities of long-term debt, including current maturities, for the Ameren Companies at December 31, 2013: Ameren (Parent)(a) Ameren Missouri(a) Ameren Illinois(a)(b) Ameren Consolidated 2014 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2015 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2016 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 425 - - - - - 425 $ 109 120 266 431 383 2,455 $ - - 129 250 457 1,023 $ 534 120 395 681 840 3,478 $ 3,764 $ 1,859 $ 6,048 (a) Excludes unamortized discount and premium of $7 million and $7 million at Ameren Missouri and Ameren Illinois, respectively. (b) Excludes $4 million related to Ameren Illinois’ long-term debt fair-market value adjustments, which are being amortized to interest expense over the remaining life of the debt. All classes of Ameren Missouri’s and Ameren Illinois’ preferred stock are entitled to cumulative dividends and have voting rights. Preferred stock not subject to mandatory redemption of Ameren’s subsidiaries was included in “Noncontrolling Interests” on Ameren’s consolidated balance sheet. The following table presents the outstanding preferred stock of Ameren Missouri and Ameren Illinois that is not subject to mandatory redemption. The preferred stock is redeemable, at the option of the issuer, at the prices shown below as of December 31, 2013, and 2012: Redemption Price (per share) 2013 2012 Ameren Missouri: Without par value and stated value of $100 per share, 25 million shares authorized 130,000 shares . . . . . . . . . . . . . . . . . . . . 40,000 shares . . . . . . . . . . . . . . . . . . . . 150,000 shares . . . . . . . . . . . . . . . . . . . . 40,000 shares . . . . . . . . . . . . . . . . . . . . 213,595 shares . . . . . . . . . . . . . . . . . . . . 200,000 shares . . . . . . . . . . . . . . . . . . . . 20,000 shares . . . . . . . . . . . . . . . . . . . . 14,000 shares . . . . . . . . . . . . . . . . . . . . $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 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 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 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 . . . . . . . . . . . . . . . . . . . . 124,274 shares . . . . . . . . . . . . . . . . . . . . 4,542 shares . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) In the event of voluntary liquidation, $105.50. 105 $ 110.00 104.75 105.625 105.00 110.00(a) 102.47 102.176 110.00 $ 101.00 103.00 104.00 102.00 103.00 103.00 103.00 102.00 103.50 102.00 100.00 100.00 $ $ $ $ $ 13 4 15 4 21 20 2 1 80 14 5 2 5 2 2 2 7 5 5 12 1 62 142 $ $ $ $ $ 13 4 15 4 21 20 2 1 80 14 5 2 5 2 2 2 7 5 5 12 1 62 142 Ameren has 100 million shares of $0.01 par value preferred stock authorized, with no shares outstanding. Ameren Missouri has 7.5 million shares of $1 par value preference stock authorized, with no such preference stock outstanding. Ameren Illinois has 2.6 million shares of no par value preferred stock authorized, with no shares outstanding. Ameren Ameren filed a Form S-8 registration statement with the SEC in October 2013, authorizing the offering of 4 million additional shares of its common stock under its 401(k) plan. Shares of common stock sold under the 401(k) plan are, at Ameren’s option, newly issued shares, treasury Ameren Missouri shares, or shares purchased in the open market or in privately negotiated transactions. Ameren filed a Form S-3 registration statement with the SEC in June 2011, authorizing the offering of 6 million additional shares of its common stock under DRPlus. Shares of common stock sold under DRPlus are, at Ameren’s option, newly issued shares, treasury shares, or shares purchased in the open market or in privately negotiated transactions. In 2013 and 2012, Ameren shares were purchased in the open market for DRPlus and its 401(k) plan. Under DRPlus and its 401(k) plan, Ameren issued 2.2 million shares of common stock in 2011, which were valued at $65 million. In October 2013, $44 million of Ameren Missouri’s 1993 5.45% Series tax-exempt first mortgage bonds were redeemed at par value plus accrued interest, and $200 million of Ameren Missouri’s 4.65% senior secured notes matured and were retired. On September 11, 2012, Ameren Missouri issued $485 million principal amount of 3.90% senior secured notes due September 15, 2042, with interest payable semiannually on March 15 and September 15 of each year, beginning March 15, 2013. These notes are secured by first mortgage bonds. Ameren Missouri received net proceeds of $478 million. The proceeds were used, together with other available cash, to provide the funds necessary to complete Ameren Missouri’s tender offer on September 20, 2012, including the payment of interest and all related fees and expenses, and to retire the $173 million principal amount 5.25% senior secured notes that matured in September 2012. On September 20, 2012, Ameren Missouri completed its tender offer to purchase for cash its outstanding 6.00% senior secured notes due 2018, 6.70% senior secured notes due 2019, 5.10% senior secured notes due 2018, and 5.10% senior secured notes due 2019. Any notes that were not tendered and purchased in the tender offer remain outstanding and continue to be obligations of Ameren Missouri. The following table sets forth the aggregate principal amount of each series of notes repurchased, along with certain other items related to the tender offer: Senior Secured Notes Principal Amount Repurchased Premium Plus Accrued and Unpaid Interest(a) Principal Amount Outstanding After Tender Offer 6.00% senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . 6.70% senior secured notes due 2019 . . . . . . . . . . . . . . . . . . . . . 5.10% senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . 5.10% senior secured notes due 2019 . . . . . . . . . . . . . . . . . . . . . $ 71 121 1 56 $ 19 35 (b) 12 $ 179 329 199 244 (a) The premiums paid in association with the tender offer were recorded as a regulatory asset and are being amortized over the life of the $485 million 3.90% senior secured notes due 2042. (b) Amount is less than $1 million. Ameren Illinois In January 2014, Ameren Illinois redeemed the following environmental improvement and pollution control revenue bonds at par value plus accrued interest: Senior Secured Notes Principal Amount 5.90% Series 1993 due 2023(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.70% 1994A Series due 2024(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 Series C-1 5.95% due 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1993 Series C-2 5.70% due 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.40% 1998A Series due 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.40% 1998B Series due 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 32 36 35 8 19 33 Total amount redeemed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 163 (a) Less than $1 million principal amount of the bonds remain outstanding as of January 31, 2014. 106 In December 2013, Ameren Illinois issued $280 million principal amount of 4.80% senior secured notes due December 15, 2043, with interest payable semiannually on June 15 and December 15 of each year, beginning June 15, 2014. These notes are secured by first mortgage bonds. Ameren Illinois received net proceeds of $276 million. The proceeds were used, together with other available cash, to repay at maturity $150 million aggregate principal amount of its 8.875% senior secured notes due December 15, 2013, and to repay its short-term debt. On August 20, 2012, Ameren Illinois issued $400 million principal amount of 2.70% senior secured notes due September 1, 2022, with interest payable semiannually on March 1 and September 1 of each year, beginning March 1, 2013. These notes are secured by first mortgage bonds. Ameren Illinois received net proceeds of $397 million. The proceeds were used, together with other available cash, to provide the funds necessary to complete Ameren Illinois’ tender offer on August 27, 2012, including the payment of interest and all related fees and expenses, and to redeem $51 million principal amount of 5.50% pollution control revenue bonds at par value plus accrued interest. On August 27, 2012, Ameren Illinois completed its tender offer to purchase for cash its outstanding 9.75% senior secured notes due 2018 and 6.25% senior secured notes due 2018. Any notes that were not tendered and purchased in the tender offer remain outstanding and continue to be obligations of Ameren Illinois. The following table sets forth the aggregate principal amount of each series of notes repurchased, along with certain other items related to the tender offer: Senior Secured Notes Principal Amount Repurchased Premium Plus Accrued and Unpaid Interest(a) Principal Amount Outstanding After Tender Offer 9.75% senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . 6.25% senior secured notes due 2018 . . . . . . . . . . . . . . . . . . . . . $ 87 194 $ 36 47 $ 313 144 (a) Premiums paid in the amount of $21 million in association with the tender offer were recorded as a regulatory asset and are being amortized over the life of the $400 million 2.70% senior secured notes due 2022. Premiums of $15 million were expensed in 2013 as a result of disallowances in the ICC’s December 2013 electric and natural gas rate orders. See Note 2 – Rate and Regulatory Matters for further information regarding the disallowances. In November 2012, $1 million principal amount of Ameren Illinois’ 6.20% Series 1992B Pollution Control revenue bonds matured and were retired. 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 and dividend coverage ratios and bonds and preferred stock issuable as of December 31, 2013, at an assumed interest rate of 6% and dividend rate of 7%. Required Interest Coverage Ratio(a) Actual Interest Coverage Ratio Ameren Missouri . . . . Ameren Illinois . . . . . . >2.0 >2.0 4.5 6.8 Bonds Issuable(b) $ 3,831 3,565(d) Required Dividend Coverage Ratio(c) Actual Dividend Coverage Ratio Preferred Stock Issuable >2.5 >1.5 116.5 2.4 $ 2,228 203 (a) 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. (b) 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 $729 million and $365 million at Ameren Missouri and Ameren Illinois, respectively. (c) Coverage required on the annual dividend on preferred stock outstanding and to be issued, as required in the respective company’s articles of incorporation. (d) Amount of bonds issuable by Ameren Illinois based on unfunded property additions and retired bonds solely under the former IP mortgage indenture. 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 the 2012 Credit Agreements, 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 Power Act, which makes it 107 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.” 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 may not pay any dividend on its stock, unless, among other things, its earnings and earned surplus are sufficient to declare and pay a dividend after provision is made for reasonable and proper reserves, or unless Ameren Illinois 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 committed to FERC to maintain a minimum 30% ratio of common stock equity to total capitalization. As of December 31, 2013, Ameren Illinois’ ratio of common stock equity to total capitalization was 55%. 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, 2013, none of the Ameren Companies had any off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business. None of the Ameren Companies expect to engage in any significant off-balance-sheet financing arrangements in the near future. See Note 16 – Divestiture Transactions and Discontinued Operations for Ameren (parent) guarantees and letters of credit issued to support New AER based on the transaction agreement with IPH. 108 NOTE 6 – OTHER INCOME AND EXPENSES The following table presents the components of “Other Income and Expenses” in the Ameren Companies’ statements of income (loss) for the years ended December 31, 2013, 2012, and 2011: 2013 2012 2011 Ameren:(a) Miscellaneous income: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income on industrial development revenue bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense: Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Miscellaneous income: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income on industrial development revenue bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense: Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Miscellaneous income: Allowance for equity funds used during construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense: Donations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ $ $ $ $ $ $ 37 27 3 2 69 12 14 26 31 27 - - 58 4 7 11 6 2 2 10 4 5 9 $ $ $ $ $ $ $ $ $ $ $ $ 36 28 4(b) 2 70 24(c) 13 37 31 28 4(b) - 63 9 5 14 5 - 2 7 11(c) 6 17 $ $ $ $ $ $ $ $ $ $ $ $ 34 28 3 3 68 8 15 23 30 28 2 1 61 3 7 10 4 1 2 7 1 5 6 (a) (b) (c) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Includes interest income received in 2012 relating to a refund of charges included in an expired power purchase agreement with Entergy. See Note 2 – Rate and Regulatory Matters for additional information. Includes Ameren Illinois’ one-time $7.5 million donation to the Illinois Science and Energy Innovation Trust pursuant to the IEIMA as a result of Ameren Illinois’ 2012 participation in the electric delivery formula ratemaking process. NOTE 7 – DERIVATIVE FINANCIAL INSTRUMENTS We use derivatives principally to manage the risk of changes in market prices for natural gas, diesel, power, and uranium. 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; and actual cash outlays for the purchase of these commodities that differ from anticipated cash outlays. ‰ 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. 109 The following table presents open gross commodity contract volumes by commodity type for derivative assets and liabilities as of December 31, 2013, and 2012. As of December 31, 2013, these contracts ran through October 2016, October 2019, May 2032, and October 2016 for fuel oils, natural gas, power, and uranium, respectively. Quantity (in millions, except as indicated) 2013 2012 Commodity Ameren Missouri Ameren Illinois Ameren Ameren Missouri Ameren Illinois Ameren Fuel oils (in gallons)(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas (in mmbtu) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power (in megawatthours) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium (pounds in thousands) 66 28 3 796 (b) 108 11 (b) 66 136 14 796 70 19 11 446 (b) 128 14 (b) 70 147 25 446 Fuel oils consist of heating oil, ultra-low-sulfur diesel, and crude oil. (a) (b) Not applicable. Authoritative accounting guidance regarding derivative instruments requires that all contracts considered to be derivative instruments 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. 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 if it qualifies for hedge accounting. We also consider whether gains or losses resulting from such derivatives 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 regulatory liabilities in the period in which the change occurs. Ameren Missouri and Ameren Illinois believe derivative gains and losses deferred as regulatory assets and regulatory liabilities are probable of recovery or refund through future rates charged to customers. Regulatory assets and regulatory 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, 2013, and 2012, all contracts that qualify for hedge accounting receive regulatory deferral. Authoritative accounting guidance permits companies to offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a liability) against fair value amounts recognized for derivative instruments that are executed with the same counterparty under the same master netting arrangement. The Ameren Companies did not elect to adopt this guidance for any eligible commodity contracts. 110 The following table presents the carrying value and balance sheet location of all derivative instruments as of December 31, 2013, and 2012: Balance Sheet Location Ameren Missouri Ameren Illinois Ameren 2013 Derivative assets not designated as hedging instruments(a) Commodity contracts: Fuel oils . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 6 3 1 23 33 Derivative liabilities not designated as hedging instruments(a) Commodity contracts: Fuel oils . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (b) Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . 2 1 (b) 5 6 (b) 4 - (b) 5 1 $ $ $ - - 1 - 1 - - - 27 - 19 9 - 99 - - - $ $ $ 6 3 2 23 34 2 - 1 32 - 25 13 - 99 5 - 1 Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 24 $ 154 $ 178 2012 Derivative assets not designated as hedging instruments(a) Commodity contracts: Fuel oils . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Natural gas . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 4 - 1 14 1 Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 28 Derivative liabilities not designated as hedging instruments(a) Commodity contracts: Fuel oils . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (b) Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities Uranium . . . . . . . . . . . . . . MTM derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . 2 2 (b) 8 7 (b) 4 - (b) 1 1 $ $ $ - - 1 - - - 1 - - - 56 - 38 21 - 90 - - - $ $ $ 8 4 1 1 14 1 29 2 - 2 64 - 45 25 - 90 1 - 1 Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 25 $ 205 $ 230 Includes derivatives subject to regulatory deferral. (a) (b) Balance sheet line item not applicable to registrant. 111 The following table presents the cumulative amount of pretax net gains (losses) on all derivative instruments deferred in regulatory assets or regulatory liabilities as of December 31, 2013, and 2012: 2013 Cumulative gains (losses) deferred in regulatory liabilities or assets: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fuel oils derivative contracts(a) Natural gas derivative contracts(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power derivative contracts(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium derivative contracts(d) 2012 Cumulative gains (losses) deferred in regulatory liabilities or assets: Fuel oils derivative contracts(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas derivative contracts(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power derivative contracts(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium derivative contracts(d) Ameren Missouri Ameren Illinois Ameren $ $ 2 (10) 19 (6) 4 (14) 12 (2) $ - (45) (108) - $ 2 (55) (89) (6) $ - (93) (111) - $ 4 (107) (99) (2) (a) Represents net gains on fuel oils derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouri’s transportation costs for coal through October 2016, as of December 31, 2013. Current gains deferred as regulatory liabilities include $3 million and $3 million at Ameren and Ameren Missouri as of December 31, 2013, respectively. Current losses deferred as regulatory assets include $1 million and $1 million at Ameren and Ameren Missouri as of December 31, 2013, respectively. (b) Represents net losses associated with natural gas derivative contracts. These contracts are a partial hedge of natural gas requirements through October 2019 at Ameren and Ameren Missouri and through March 2017 at Ameren Illinois, in each case as of December 31, 2013. Current gains deferred as regulatory liabilities include $2 million, $1 million, and $1 million at Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2013. Current losses deferred as regulatory assets include $32 million, $5 million, and $27 million at Ameren, Ameren Missouri and Ameren Illinois, respectively, as of December 31, 2013. (c) Represents net gains (losses) associated with power derivative contracts. These contracts are a partial hedge of power price requirements through May 2032 at Ameren and Ameren Illinois and through December 2015 at Ameren Missouri, in each case as of December 31, 2013. Current gains deferred as regulatory liabilities include $23 million and $23 million at Ameren and Ameren Missouri, respectively, as of December 31, 2013. Current losses deferred as regulatory assets include $13 million, $4 million, and $9 million at Ameren, Ameren Missouri and Ameren Illinois, respectively, as of December 31, 2013. (d) Represents net losses on uranium derivative contracts at Ameren Missouri. These contracts are a partial hedge of Ameren Missouri’s uranium requirements through October 2016, as of December 31, 2013. Current losses deferred as regulatory assets include $5 million and $5 million at Ameren and Ameren Missouri as of December 31, 2013, respectively. Derivative instruments are subject to various credit-related losses in the event of nonperformance by counterparties to the transaction. Exchange-traded contracts are supported by the financial and credit quality of the clearing members of the respective exchanges and have nominal credit risk. In all other transactions, we are exposed to credit risk. Our credit risk management program involves establishing credit limits and collateral requirements for counterparties, using master trading and netting agreements, and reporting daily exposure to senior management. We believe that entering into master trading and netting agreements mitigates the level of financial loss that could result from default by allowing net settlement of derivative assets and liabilities. We generally enter into the following master trading and netting agreements: (1) the International Swaps and Derivatives Association Agreement, a standardized financial natural gas and electric contract; (2) the Master Power Purchase and Sale Agreement, created by the Edison Electric Institute and the National Energy Marketers Association, a standardized contract for the purchase and sale of wholesale power; and (3) the North American Energy Standards Board Inc. agreement, a standardized contract for the purchase and sale of natural gas. These master trading and netting agreements allow the counterparties to net settle sale and purchase transactions. Further, collateral requirements are calculated at the master trading and netting agreement level by counterparty. 112 Although Ameren had not previously elected to offset fair value amounts and collateral for derivative instruments executed with the same counterparty under the same master netting arrangement, authoritative accounting guidance, effective in the first quarter 2013, requires those amounts eligible to be offset to be presented both at the gross and net amounts. 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, 2013, and 2012: Gross Amounts Not Offset in the Balance Sheet Gross Amounts Recognized in the Balance Sheet Derivative Instruments Cash Collateral Received/Posted(a) Net Amount 2013 Commodity contracts eligible to be offset: Assets: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ 33 1 34 24 154 Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 178 2012 Commodity contracts eligible to be offset: Assets: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ 28 1 29 25 205 Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 230 $ $ $ $ $ $ $ $ 9 1 10 9 1 10 9 1 10 9 1 10 $ $ $ $ $ $ $ $ - - - 9 15 24 - - - 7 58 65 $ $ $ 24 - 24 6 138 $ 144 $ $ $ 19 - 19 9 146 $ 155 (a) Cash collateral received reduces gross asset balances and is included in “Other current liabilities” and “Other deferred credits and liabilities” on the balance sheet. Cash collateral posted reduces gross liability balances and is included in “Other current assets” and “Other assets” on the balance sheet. Concentrations of 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. We calculate maximum exposures based on the gross fair value of financial instruments, including accrual and NPNS contracts. As of December 31, 2013, if counterparty groups were to fail completely to perform on contracts, Ameren, Ameren Missouri, and Ameren Illinois’ maximum exposure was $13 million, $12 million, and $1 million, respectively. As of December 31, 2012, if counterparty groups were to fail completely to perform on contracts, Ameren, Ameren Missouri, and Ameren Illinois’ maximum exposure was $23 million, $22 million, and $1 million, respectively. The potential loss on counterparty exposures is reduced by the application of master trading and netting agreements and collateral held to the extent of reducing the exposure to zero. As of December 31, 2013, the potential loss after consideration of the application of master trading and netting agreements and collateral held for Ameren and Ameren Missouri was $6 million and $6 million, respectively. As of December 31, 2012, the potential loss after consideration of the application of master trading and netting agreements and collateral held for Ameren and Ameren Missouri was $15 million and $15 million, respectively. 113 Derivative Instruments with Credit Risk-Related Contingent Features Our commodity contracts contain collateral provisions tied to the Ameren Companies’ credit ratings. If we were to experience an adverse change in our credit ratings, or if a counterparty with reasonable grounds for uncertainty regarding performance of an obligation requested adequate assurance of performance, additional collateral postings might be required. The following table presents, as of December 31, 2013, and 2012, the aggregate fair value of all derivative instruments with credit risk-related contingent features in a gross liability position, the cash collateral posted, and the aggregate amount of additional collateral that could be required to be posted with counterparties. The additional collateral required is the net liability position allowed under the master trading and netting agreements assuming (1) the credit risk-related contingent features underlying these agreements were triggered on December 31, 2013, or 2012, respectively, and (2) those counterparties with rights to do so requested collateral: Aggregate Fair Value of Derivative Liabilities(a) Cash Collateral Posted Potential Aggregate Amount of Additional Collateral Required(b) 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ 70 75 145 78 148 226 $ $ $ $ 2 15 17 3 58 61 $ $ $ $ 67 55 122 71 84 155 (a) Prior to consideration of master trading and netting agreements and including NPNS and accrual contract exposures. (b) As collateral requirements with certain counterparties are based on master trading and netting agreements, the aggregate amount of additional collateral required to be posted is determined after consideration of the effects of such agreements. Derivatives Subject to Regulatory Deferral The following table represents the net change in market value associated with derivatives that qualify for regulatory deferral for the years ended December 31, 2013 and 2012: Ameren(a) Ameren Missouri Ameren Illinois Gain (Loss) Recognized in Regulatory Liabilities or Regulatory Assets 2012 2013 Fuel oils . . . . . . . . . . . . . Natural gas . . . . . . . . . . . Power . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . Total Fuel oils . . . . . . . . . . . . . Natural gas . . . . . . . . . . . Power . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . Total Natural gas . . . . . . . . . . . Power . . . . . . . . . . . . . . . Total $ $ $ $ $ $ (2) 52 10 (4) 56 (2) 4 7 (4) 5 48 3 51 $ (15) 84 (180) (1) $ (112) $ $ $ $ (15) 10 (9) (1) (15) 74 29 103 (a) Amounts include intercompany eliminations. NOTE 8 – FAIR VALUE MEASUREMENTS Fair value is defined as the exchange 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: Inputs based on quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities are primarily exchange-traded derivatives and assets, including cash and cash equivalents and listed equity securities, such as those held in Ameren Missouri’s nuclear decommissioning trust fund. 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. Level 2: Market-based inputs corroborated by third- party brokers or exchanges based on transacted market data. Level 2 assets and liabilities include certain assets 114 held in Ameren Missouri’s nuclear decommissioning trust fund, including corporate bonds and other fixed-income securities, United States treasury and agency securities, and certain over-the-counter derivative instruments, including natural gas and financial power transactions. Fixed income securities are valued 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. Level 2 fixed income securities in the nuclear decommissioning trust fund are primarily corporate bonds, asset-backed securities and United States agency bonds. 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 midpoints of the bid/ask spreads. To validate forward prices obtained from outside parties, we compare the pricing to recently settled market transactions. 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 midpoint. Natural gas derivative contracts are valued based upon exchange closing prices without significant unobservable adjustments. Power derivatives contracts are valued based upon the use of multiple forward prices provided by third parties. The prices are averaged and shaped to a monthly profile when needed without significant unobservable adjustments. Level 3: 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, as well as certain internal assumptions. Our development and corroboration process entails obtaining multiple quotes or prices from outside sources. As a part of our reasonableness review, an evaluation of all sources is performed to identify any anomalies or potential errors. 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. The following table describes the valuation techniques and unobservable inputs for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the period ended December 31, 2013: Fair Value Assets Liabilities Valuation Technique(s) Unobservable Input Range Weighted Average Ameren Level 3 Derivative asset and liability – commodity contracts(a): Option model Discounted cash flow Discounted cash flow Fuel oils Power(e) (110) $ 8 (3) 21 $ Fundamental energy production model Contract price allocation Uranium - (6) Discounted cash flow 10 - 35 0.26 - 2 25 - 51 Volatilities(%)(b) Counterparty credit risk(%)(c)(d) Average forward peak and off-peak pricing - forwards/swaps($/MWh)(c) Estimated auction price for FTRs($/MW)(b) Nodal basis($/MWh)(c) Counterparty credit risk(%)(c)(d) Ameren credit risk(%)(c)(d) Estimated future gas prices($/mmbtu)(b) 4 - 5 (1,594) - 945 (3) - (1) 0.39 - 0.50 2 Escalation rate(%)(b)(g) Estimated renewable energy credit costs($/credit)(b) Average bid/ask consensus pricing($/pound)(b) Ameren Missouri Fuel oils $ 8 $ (3) Option model Volatilities(%)(b) Power(e) 21 (2) Discounted cash flow Discounted cash flow Uranium - (6) Discounted cash flow Counterparty credit risk(%)(c)(d) Average forward peak and off-peak pricing - forwards/swaps($/MWh)(c) Estimated auction price for FTRs($/MW)(b) Nodal basis($/MWh)(c) Counterparty credit risk(%)(c)(d) Ameren Missouri credit risk(%)(c)(d) Average bid/ask consensus pricing($/pound)(b) 115 16 1 32 305 (2) 0.42 (f) 5 4 6 36 16 1 40 305 (2) 0.42 (f) 36 3 - 4 5 - 7 34 - 41 10 - 35 0.26 - 2 25 - 51 (1,594) - 945 (3) - (1) 0.39 - 0.50 2 34 - 41 Fair Value Assets Liabilities Valuation Technique(s) Unobservable Input Range Ameren Illinois Power(e) $ - $ (108) Discounted cash flow Fundamental energy production model Contract price allocation Average forward peak and off-peak pricing - forwards/swaps($/MWh)(b) Nodal basis($/MWh)(b) Ameren Illinois credit risk(%)(c)(d) Estimated future gas prices($/mmbtu)(b) 4 - 5 (4) - 0 2 27 - 36 Escalation rate(%)(b)(g) Estimated renewable energy credit costs($/credit)(b) 3 - 4 5 - 7 Weighted Average 30 (2) (f) 5 4 6 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (c) Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. (d) Counterparty credit risk is applied only to counterparties with derivative asset balances. Ameren, Ameren Missouri and Ameren Illinois credit risk is applied only to counterparties with derivative liability balances. (e) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2017. Valuations beyond 2017 use fundamentally modeled pricing by month for peak and off-peak demand. (f) Not applicable. (g) Escalation rate applies to power prices 2026 and beyond. The following table describes the valuation techniques and unobservable inputs for the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of December 31, 2012: Fair Value Assets Liabilities Valuation Technique Unobservable Input Range Level 3 Derivative asset and liability – commodity contracts(a): Ameren Fuel oils $ 8 $ (3) Option model Discounted cash flow Power(f) 14 (114) Discounted cash flow Fundamental energy production model Contract price allocation Uranium - (2) Discounted cash flow 7 - 27 0.21 - 0.60 0.12 - 1 2 22 - 47 Volatilities(%)(b) Escalation rate(%)(b) Counterparty credit risk(%)(c)(d) Ameren credit risk(%)(c)(d) Average forward peak and off-peak power pricing - forwards/swaps($/MWh)(c) Estimated auction price for FTRs ($/MW)(b) (5) - (1) Nodal basis($/MWh)(c) 0.22 - 1 Counterparty credit risk(%)(c)(d) Ameren credit risk(%)(c)(d) 2 - 5 Estimated future gas prices($/mmbtu)(b) 4 - 8 (281) - 1,851 Estimated renewable energy credit costs ($/credit)(b) Average forward uranium pricing ($/pound)(b) Ameren Missouri Fuel oils $ 8 $ (3) Option model Volatilities(%)(b) Discounted cash flow Power(f) 14 (3) Discounted cash flow Uranium - (2) Discounted cash flow Escalation rate(%)(b) Counterparty credit risk(%)(c)(d) Ameren Missouri credit risk(%)(c)(d) Average forward peak and off-peak power pricing - forwards/swaps($/MWh)(c) Estimated auction price for FTRs ($/MW)(b) Nodal basis($/MWh)(c) Counterparty credit risk(%)(c)(d) Ameren Missouri credit risk(%)(c)(d) Average forward uranium pricing ($/pound)(b) 116 Weighted Average 24 0.44 1 (e) 31 178 (3) 1 5 6 6 44 24 0.44 1 (e) 36 5 - 7 43 - 46 7 - 27 0.21 - 0.60 0.12 - 1 2 24 - 56 (281) - 1,851 178 (5) - (1) 0.22 - 1 2 43 - 46 (2) 1 (e) 44 Fair Value Assets Liabilities Valuation Technique Unobservable Input Range Ameren Illinois Power(f) $ - $ (111) Discounted cash flow Fundamental energy production model Contract price allocation Average forward peak and off-peak power pricing - forwards/swaps($/MWh)(b) Nodal basis($/MWh)(b) Ameren Illinois credit risk(%)(c)(d) Estimated future gas prices($/mmbtu)(b) 4 - 8 (5) - (1) 5 22 - 47 Estimated renewable energy credit costs($/credit)(b) 5 - 7 Weighted Average 30 (3) (e) 6 6 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (c) Generally, significant increases (decreases) in this input in isolation would result in a significantly lower (higher) fair value measurement. (d) Counterparty credit risk is applied only to counterparties with derivative asset balances. Ameren, Ameren Missouri and Ameren Illinois credit risk is applied only to counterparties with derivative liability balances. (e) Not applicable. (f) Power valuations use visible third-party pricing evaluated by month for peak and off-peak demand through 2017. Valuations beyond 2017 use fundamentally modeled pricing by month for peak and off-peak demand. In accordance with applicable authoritative accounting guidance, we consider nonperformance risk in our valuation of derivative instruments by analyzing the credit standing of our counterparties and considering any counterparty credit enhancements (e.g., collateral). The guidance also requires that the fair value measurement of liabilities reflect the nonperformance risk of the reporting entity, as applicable. Therefore, we have factored the impact of our credit standing, as well as any potential credit enhancements, into the fair value measurement of both derivative assets and derivative liabilities. 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. Ameren recorded no gains or losses related to valuation adjustments for counterparty default risk in 2013, 2012 or 2011. At December 31, 2013, the counterparty default risk liability valuation adjustment related to derivative contracts totaled $3 million, less than $1 million, and $3 million, for Ameren, Ameren Missouri, and Ameren Illinois, respectively. At December 31, 2012, the counterparty default risk liability valuation adjustment related to derivative contracts totaled $7 million, less than $1 million, and $7 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively. 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, 2013: Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Assets: Ameren Derivative assets – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power Total derivative assets – commodity contracts . . . . . . Nuclear decommissioning trust fund: Cash and cash equivalents . . . . . . . . . . . . . . . . . . Equity securities: $ $ $ 1 - - 1 3 U.S. large capitalization . . . . . . . . . . . . . . . . 332 Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . Asset-backed securities . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - - - - $ $ $ - 2 2 4 - - 52 2 94 10 1 Total nuclear decommissioning trust fund . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 335 336 $ $ 159 163 $ $ $ $ $ 8 - 21 29 - - - - - - - - 29 Total $ $ $ 9 2 23 34 3 332 52 2 94 10 1 $ $ 494 528 117 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Ameren Missouri Derivative assets – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power Total derivative assets – commodity contracts . . . . . . Nuclear decommissioning trust fund: Cash and cash equivalents . . . . . . . . . . . . . . . . . . Equity securities: $ $ $ 1 - - 1 3 U.S. large capitalization . . . . . . . . . . . . . . . . 332 Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . Asset-backed securities . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total nuclear decommissioning trust fund . . . . . . . . . Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . Derivative assets – commodity contracts(a): Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Missouri Ameren Illinois Liabilities: Ameren Ameren Missouri Ameren Illinois Derivative liabilities – commodity contracts(a): Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Power Total Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . - - - - - 335 336 - - 3 - - 3 - 3 - - 3 - - - $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ - 1 2 3 - - 52 2 94 10 1 159 162 1 - 54 2 - 56 - 8 2 - 10 46 - 46 $ $ $ $ $ $ $ 8 - 21 29 - - - - - - - - 29 - 3 - 110 6 $ 119 $ $ $ 3 - 2 6 11 - 108 $ 108 $ $ $ $ $ $ $ $ $ $ $ $ 9 1 23 33 3 332 52 2 94 10 1 494 527 1 3 57 112 6 178 3 11 4 6 24 46 108 154 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. 118 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, 2012: Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Total Assets: Ameren Ameren Missouri Derivative assets – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total derivative assets – commodity contracts . . . . Nuclear decommissioning trust fund: Cash and cash equivalents . . . . . . . . . . . . . . . Equity securities: $ $ $ 4 - - 4 1 U.S. large capitalization . . . . . . . . . . . . . 264 Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . Asset-backed securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Total nuclear decommissioning trust fund . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative assets – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total derivative assets – commodity contracts . . . . Nuclear decommissioning trust fund: Cash and cash equivalents . . . . . . . . . . . . . . . Equity securities: - - - - - 265 269 4 - - 4 1 $ $ $ $ $ U.S. large capitalization . . . . . . . . . . . . . 264 Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . Asset-backed securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Total nuclear decommissioning trust fund . . . . . . . Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . Derivative assets – commodity contracts(a): Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities – commodity contracts(a): Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Uranium . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Liabilities: Ameren Ameren Missouri - - - - - 265 269 - 1 7 - - 8 1 7 - - 8 $ $ $ $ $ $ $ 119 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ - 2 1 3 - - 47 1 81 11 1 141 144 - 1 1 2 - - 47 1 81 11 1 141 143 1 - 102 1 - 103 - 8 1 - 9 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 8 - 14 22 - - - - - - - - 22 8 - 14 22 - - - - - - - - 22 - 3 - 114 2 119 3 - 3 2 8 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 12 2 15 29 1 264 47 1 81 11 1 406(b) 435 12 1 15 28 1 264 47 1 81 11 1 406(b) 434 1 4 109 115 2 230 4 15 4 2 25 Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Ameren Illinois Derivative liabilities – commodity contracts(a): Natural gas . . . . . . . . . . . . . . . . . . . . . . . Power . . . . . . . . . . . . . . . . . . . . . . . . . . . Total Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . $ — — $ — $ $ 94 — 94 $ — 111 $ 111 Total $ $ 94 111 205 (a) The derivative asset and liability balances are presented net of counterparty credit considerations. (b) Balance excludes $2 million of receivables, payables, and accrued income, net. The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of December 31, 2013: Net Derivative Commodity Contracts Ameren Ameren Illinois Missouri Ameren Fuel oils: Beginning balance at January 1, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5 $ Realized and unrealized gains (losses): Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total realized and unrealized gains (losses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31,2013 . . . . . . . . . . . . . . Natural gas: Beginning balance at January 1, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total realized and unrealized gains (losses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2013 . . . . . . . . . . . . . Power: Beginning balance at January 1, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total realized and unrealized gains (losses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers into Level 3 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2013 . . . . . . . . . . . . . Uranium: Beginning balance at January 1, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total realized and unrealized gains (losses) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2013 . . . . . . . . . . . . . $ $ $ $ $ $ $ $ $ $ $ (a) Not applicable. 120 (a) (a) (a) (a) (a) (a) (a) (a) - (1) (1) 1 - - $ 5 - - 3 (1) (2) 5 - - (1) (1) 1 - - $ $ $ $ $ - - 3 (1) (2) 5 - - - - - - - $ $ $ $ $ 11 $ (111) $ (100) 3 3 40 (36) (3) 4 19 (1) (2) (3) (3) (2) 1 (6) (2) (18) (18) - 21 - - $ (108) $ (24) $ $ $ (a) (a) (a) (a) (a) (a) (a) (15) (15) 40 (15) (3) 4 (89) (25) (2) (3) (3) (2) 1 (6) (2) $ $ $ $ $ The following table summarizes the changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy as of December 31, 2012: Net Derivative Commodity Contracts Ameren Illinois Ameren Missouri Ameren Fuel oils: Beginning balance at January 1, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3 $ Realized and unrealized gains (losses): Total realized and unrealized gains (losses) Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers into Level 3 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2012 . . . . . . . . . . . . . . Natural gas: Beginning balance at January 1, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Total realized and unrealized gains (losses) Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2012 . . . . . . . . . . . . . . Power(b): Beginning balance at January 1, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Total realized and unrealized gains (losses) Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Sales . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2012 . . . . . . . . . . . . . . Uranium: Beginning balance at January 1, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Realized and unrealized gains (losses): Total realized and unrealized gains (losses) Included in regulatory assets/liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ending balance at December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Change in unrealized gains (losses) related to assets/liabilities held at December 31, 2012 . . . . . . . . . . . . . . (1) (1) 7 (3) (2) 1 5 (1) (14) (2) (2) 1 15 - - 21 11 11 21 (1) (37) (4) 11 - (1) (2) (2) 1 (2) (1) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ (a) (a) (a) (a) (a) (a) (a) (a) (a) (160) (25) (25) 15 170 - - (140) (226) (226) - - 255 - (111) (191)(c) (a) (a) (a) (a) (a) (a) $ $ $ $ $ $ $ $ $ $ $ $ 3 (1) (1) 7 (3) (2) 1 5 (1) (174) (27) (27) 16 185 - - 81 (175) (175) 21 (1) (22) (4) (100) (175) (1) (2) (2) 1 (2) (1) (a) Not applicable. (b) Ameren amounts include intercompany eliminations. (c) The change in unrealized losses was due to decreases in long-term power prices applied to 20-year Ameren Illinois swap contracts, which expire in May 2032. 121 Transfers in or out of Level 3 represent either (1) existing assets and liabilities that were previously categorized as a higher level but were recategorized to Level 3 because the inputs to the model became unobservable during the period, or (2) existing assets and liabilities that were previously classified as Level 3 but were recategorized to a higher level because the lowest significant input became observable during the period. Transfers out of Level 3 into Level 2 for natural gas derivatives were due to management previously using broker quotations to estimate the fair value of natural gas contracts and changing to estimates based upon exchange closing prices without significant unobservable adjustments in 2012. Estimates of fair value based on exchange closing prices are deemed to be a more accurate approximation of natural gas prices. Transfers between Level 2 and Level 3 for power derivatives and between Level 1 and Level 3 for fuel oils were primarily caused by changes in availability of financial trades observable on electronic exchanges between the periods shown below. Any reclassifications are reported as transfers out of Level 3 at the fair value measurement reported at the beginning of the period in which the changes occur. For the years ended December 31, 2013 and 2012, there were no transfers between Level 1 and Level 2 related to derivative commodity contracts. The following table summarizes all transfers between fair value hierarchy levels related to derivative commodity contracts for the years ended December 31, 2013 and 2012: Ameren – derivative commodity contracts: Transfers into Level 3 / Transfers out of Level 1 – Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 / Transfers into Level 2 – Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers into Level 3 / Transfers out of Level 2 – Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 / Transfers into Level 2 – Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net fair value of Level 3 transfers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri – derivative commodity contracts: Transfers into Level 3 / Transfers out of Level 1 – Fuel oils . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 / Transfers into Level 2 – Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers into Level 3 / Transfers out of Level 2 – Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transfers out of Level 3 / Transfers into Level 2 – Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net fair value of Level 3 transfers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois – derivative commodity contracts: Transfers out of Level 3 / Transfers into Level 2 – Natural gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2013 2012 $ $ $ $ $ - - (3) 4 1 - - (3) 4 1 - $ $ $ $ $ 1 185 - (4) 182 1 15 - (4) 12 170 See Note 11 – Retirement Benefits for the fair value hierarchy tables detailing Ameren’s pension and postretirement plan assets as of December 31, 2013, as well as a table summarizing the changes in Level 3 plan assets during 2013. The Ameren Companies’ carrying amounts of cash and cash equivalents approximate fair value because of the short-term nature of these instruments and are considered to be Level 1 in the fair value hierarchy. Ameren’s and Ameren Missouri’s carrying amounts of investments in debt securities related to the two CTs from the city of Bowling Green and Audrain County approximate fair value. These investments are classified as held-to-maturity. These investments are considered Level 2 in the fair value hierarchy as they are valued based on similar market transactions. The Ameren Companies’ short-term borrowings also approximate fair value because of their short-term nature. Short-term borrowings are considered to be Level 2 in the fair value hierarchy as they are valued based on market rates for similar market transactions. The estimated fair value of long-term debt and preferred stock is based on the quoted market prices for same or similar issuances for companies with similar credit profiles or on the current rates offered to the Ameren Companies for similar financial instruments, which fair value measurement is considered Level 2 in the fair value hierarchy. The following table presents the carrying amounts and estimated fair values of our long-term debt and preferred stock at December 31, 2013 and 2012: 2013 Carrying Amount Fair Value 2012 Carrying Amount Fair Value Ameren:(a) Long-term debt and capital lease obligations (including current portion) . . . . . Preferred stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Long-term debt and capital lease obligations (including current portion) . . . . . Preferred stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Long-term debt (including current portion) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Preferred stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ 6,038 142 3,757 80 1,856 62 $ $ $ 6,584 118 4,124 71 2,028 47 $ $ $ 6,157 142 4,006 80 1,727 62 $ $ $ 7,110 123 4,625 74 2,020 49 (a) Preferred stock is recorded in “Noncontrolling Interests” on the consolidated balance sheet. 122 NOTE 9 – NUCLEAR DECOMMISSIONING TRUST FUND INVESTMENTS and losses resulting from those sales for the years ended December 31, 2013, 2012, and 2011: Ameren Missouri has investments in debt and equity securities that are held in a trust fund for the purpose of funding the decommissioning of its Callaway energy center. We have classified these investments as available for sale, and we have recorded all such investments at their fair market value at December 31, 2013, and 2012. See Note 10 – Callaway Energy Center for additional information. 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 following table presents proceeds from the sale and maturities of investments in Ameren Missouri’s nuclear decommissioning trust fund and the gross realized gains 2013 2012 2011 Proceeds from sales and maturities . . . . . . . . . . . . . . . . . Gross realized gains . . . . . . . . . . . Gross realized losses . . . . . . . . . . $ 196 7 5 $ 384 6 2 $ 199 5 4 Net realized and unrealized gains and losses are deferred and recorded as regulatory assets or regulatory liabilities on Ameren’s and Ameren Missouri’s balance sheets. This reporting is consistent with the method used to account for the decommissioning costs recovered in rates. Gains or losses associated with assets in the trust fund could result in lower or higher funding requirements for decommissioning costs, which are expected to be reflected in electric rates paid by Ameren Missouri’s customers. See Note 2 – Rate and Regulatory Matters. The following table presents the costs and fair values of investments in debt and equity securities in Ameren Missouri’s nuclear decommissioning trust fund at December 31, 2013, and 2012: Security Type Cost Gross Unrealized Gain Gross Unrealized Loss Fair Value 2013 Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(b) $ 157 137 3 (a) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 297 2012 Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(b) $ Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 133 145 1 2 281 $ $ $ 4 199 - - 203 8 130 - - $ 138 $ $ 2 4 - - 6 $ (a) 11 - - $ 11 $ 159 332 3 (a) $ 494 $ $ 141 264 1 2 408 (a) Amount less than $1 million. (b) Represents payables relating to pending security purchases, net of receivables related to pending security sales and interest receivables. The following table presents the costs and fair values of investments in debt securities in Ameren Missouri’s nuclear decommissioning trust fund according to their contractual maturities at December 31, 2013: Less than 5 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 years to 10 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Due after 10 years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost $ 93 31 33 Fair Value $ 94 32 33 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 157 $ 159 123 We have unrealized losses relating to certain available-for-sale investments included in our decommissioning trust fund, recorded as regulatory assets as discussed above. Decommissioning will not occur until the operating license for our nuclear energy center expires. Ameren Missouri submitted a license extension application to the NRC to extend the Callaway energy center’s operating license to 2044. The following table presents the fair value and the gross unrealized losses of the available-for-sale securities held in Ameren Missouri’s nuclear decommissioning trust fund. They are aggregated by investment category and the length of time that individual securities have been in a continuous unrealized loss position at December 31, 2013: Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 72 6 78 $ $ 2 (a) 2 $ $ (a) 7 7 $ $ (a) 4 4 $ $ 72 13 85 Less than 12 Months Gross Unrealized Losses Fair Value 12 Months or Greater Gross Unrealized Losses Fair Value Fair Value Total Gross Unrealized Losses $ $ 2 4 6 (a) Amount less than $1 million. NOTE 10 – CALLAWAY ENERGY CENTER Under the NWPA, the DOE is responsible for disposing of spent nuclear fuel from the Callaway energy center and other commercial nuclear energy centers. Under the NWPA, Ameren and other utilities that own and operate those energy centers are responsible for paying the disposal costs. The NWPA established the fee that these utilities pay the federal government for disposing of the spent nuclear fuel at one mill, or one-tenth of one cent, for each kilowatthour generated by those plants and sold. The NWPA also requires the DOE to review the nuclear waste fee against the cost of the nuclear waste disposal program and to propose to the United States Congress any fee adjustment necessary to offset the costs of the program. As required by the NWPA, Ameren Missouri and other utilities have entered into standard contracts with the federal government. The government, represented by the DOE, is responsible for implementing these provisions of the NWPA. Consistent with the NWPA and its standard contract, Ameren Missouri collects one mill from its electric customers for each kilowatthour of electricity that it generates and sells from its Callaway energy center. Although both the NWPA and the standard contract stated that the federal government would begin to dispose of spent nuclear fuel by 1998, the federal government is not meeting its disposal obligation. Ameren Missouri has sufficient installed capacity at the Callaway energy center to store its spent nuclear fuel generated through 2020, and it has the capability for additional storage capacity for spent nuclear fuel generated through the end of the energy center’s current licensed life. 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. fuel. The DOE’s plan calls for a pilot interim storage facility to begin operation with an initial focus on accepting spent nuclear fuel from shutdown reactor sites by 2021. By 2025, a larger interim storage facility would be available, co- located with the pilot facility. The plan also proposes to site a permanent geological repository by 2026, to characterize the site and to design and to license the repository by 2042, and to begin operation by 2048. In view of the federal government’s efforts to terminate the Yucca Mountain program, the Nuclear Energy Institute, a number of individual utilities, and the National Association of Regulatory Utility Commissioners sued the DOE in the United States Court of Appeals for the District of Columbia Circuit, seeking the suspension of the one mill nuclear waste fee, alleging that the DOE failed to undertake an appropriate fee adequacy review reflecting the current unsettled state of the nuclear waste program. In a June 2012 decision, the court ruled that DOE’s fee adequacy review was legally inadequate and remanded the matter to the DOE. Although the court ruled it has the power to direct the DOE to suspend the fee, the court decided that it was premature to do so. Instead, the court ordered the DOE to provide within six months a revised assessment of the amount that should be collected. In January 2013, the DOE issued the revised assessment required by the court. The DOE determined that “neither insufficient nor excess revenues are being collected,” and it proposed no adjustment to the one mill nuclear waste fee. In November 2013, the court rejected the DOE’s revised assessment and ordered the DOE to submit a proposal to the United States Congress to reduce the fee to zero. The DOE filed for rehearing, however there is no deadline for the court to act. In January 2014, the DOE, pursuant to the court’s November 2013 order, submitted to Congress a proposal to reduce the fee to zero. In January 2009, the federal government announced As a result of the DOE’s failure to begin to dispose of that a spent nuclear fuel repository at Yucca Mountain, Nevada was unworkable. The federal government took steps to terminate the Yucca Mountain program, while acknowledging its continuing obligation to dispose of utilities’ spent nuclear fuel. In January 2013, the DOE issued its plan for the management and disposal of spent nuclear the utilities’ spent nuclear fuel and fulfill its contractual obligations, Ameren Missouri and other nuclear energy center owners have also sued the DOE to recover costs incurred for ongoing storage of their spent fuel. Ameren Missouri filed a breach of contract lawsuit to recover costs that it incurred through 2009. It sought reimbursement for 124 the cost of reracking the Callaway energy center’s spent fuel pool, as well as certain NRC fees, and Missouri ad valorem taxes that Ameren Missouri would not have incurred had the DOE performed its contractual obligations. In June 2011, the parties reached a settlement agreement that included a payment to Ameren Missouri of $11 million for spent fuel storage and related costs through 2010. In addition, the settlement agreement provides for annual recovery of additional spent fuel storage and related costs incurred from 2011 through 2013 with the ability to extend the recovery period as mutually agreed to by the parties. The parties have agreed in principle to extend the recovery period through 2016. As a result of the settlement agreement, Ameren Missouri recorded a pretax reduction of $2 million and $2 million to its “Operating Expenses – Depreciation and amortization” and “Operating Expenses – Other operations and maintenance” expense line items, respectively, on its statement of income for the year ended December 31, 2011. In 2012, Ameren Missouri received a 2011 cost reimbursement of $1 million and reduced its “Property and plant, net” assets on its balance sheet by that amount. In 2013, Ameren Missouri received a 2012 cost reimbursement of $6 million and reduced its “Property and plant, net” assets on its balance sheet by that amount. In March 2014, Ameren Missouri plans to submit approximately $15 million of 2013 costs to the DOE for reimbursement pursuant to the settlement agreement. Ameren Missouri reduced its “Property and plant, net” assets by this amount with an offset to “Miscellaneous accounts and notes receivable” on its balance sheet as of December 31, 2013. Included in these reimbursements are costs related to a dry spent fuel storage facility Ameren Missouri is constructing at its Callaway energy center. Ameren Missouri intends to begin transferring spent fuel assemblies to this facility in 2015. Until the facility is completed, Ameren Missouri will, in accordance with the settlement agreement, apply for reimbursement from the DOE for the cost to construct the dry spent fuel storage facility along with related allowable costs. In December 2011, Ameren Missouri submitted a license extension application to the NRC to extend its Callaway energy center’s operating license from 2024 to 2044. There is no deadline by which the NRC must act on this application. Among the rules that the NRC has historically relied upon in approving license extensions are rules dealing with the storage of spent nuclear fuel at the reactor site and with the NRC’s confidence that permanent disposal of spent nuclear fuel will be available when needed. In a June 2012 decision, the United States Court of Appeals for the District of Columbia Circuit vacated these rules and remanded the case to the NRC, holding that the NRC’s obligations under the National Environmental Policy Act required a more thorough environmental analysis in support of the NRC’s waste confidence decision. In June 2012, a number of groups petitioned the NRC to suspend final licensing decisions in certain NRC licensing proceedings, including the Callaway license extension, until the NRC completed its proceedings on the vacated rules. In August 2012, the NRC stated that it would not issue licenses dependent on the vacated rules until it appropriately addressed the court’s remand. In September 2012, the NRC directed its staff to issue, within two years, a generic environmental impact statement and a final rule to address the court’s ruling. The NRC also stated that a site-specific analysis of these issues could be conducted in rare circumstances. If the Callaway energy center’s license is extended, additional spent fuel storage will be required. Electric utility 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 an assumed 40-year life of the nuclear center, ending with the expiration of the energy center’s current operating license in 2024. It is assumed that the Callaway energy center site will be decommissioned through the immediate dismantlement method and removed from service. Ameren and Ameren Missouri have recorded an ARO for the Callaway energy center decommissioning costs at fair value, which represents the present value of estimated future cash outflows. Decommissioning costs are included in the costs of service used to establish electric rates for Ameren Missouri’s customers. These costs amounted to $7 million in each of the years 2013, 2012, and 2011. Every three years, the MoPSC requires Ameren Missouri to file an updated cost study and funding analysis for decommissioning its Callaway energy center. Electric rates may be adjusted at such times to reflect changed estimates. The last cost study and funding analysis were filed with the MoPSC in September 2011. In October 2012, the MoPSC issued an order approving the stipulation and agreement between Ameren Missouri and the MoPSC staff that maintained the current rate of deposits to the trust fund and the rate of return assumptions used in the analysis. If Ameren Missouri’s operating license extension application is approved by the NRC, a revised funding analysis will be prepared, and the rates charged to customers will be adjusted accordingly to reflect the operating license extension at the time the next triennial cost study and funding analysis is approved by the MoPSC. Amounts collected from customers are deposited in an external trust fund to provide for the Callaway energy center’s decommissioning. If the assumed return on trust assets is not earned, we believe that it is probable that any such earnings deficiency will be recovered in rates. The fair value of the nuclear decommissioning trust fund for Ameren Missouri’s Callaway energy center is reported as “Nuclear decommissioning trust fund” in Ameren’s and Ameren Missouri’s balance sheets. This amount is legally restricted and may be used only to fund the costs of nuclear decommissioning. Changes in the fair value of the trust fund are recorded as an increase or decrease to the nuclear decommissioning trust fund, with an offsetting adjustment to the related regulatory liability. See Note 2 – Rate and Regulatory Matters and Note 9 – Nuclear Decommissioning Trust Fund Investments for additional information related to the Callaway energy center. 125 NOTE 11 – 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 offers defined benefit pension and postretirement benefit plans covering substantially all of its employees. Ameren uses a measurement date of December 31 for its pension and postretirement benefit plans. Ameren Missouri and Ameren Illinois each participate in Ameren’s single-employer pension and other postretirement plans. Ameren’s qualified pension plan is the Ameren Retirement Plan. Ameren also has an unfunded nonqualified pension plan, the Ameren Supplemental Retirement Plan, which is available for certain management employees and retirees to provide a supplemental benefit when their qualified pension plan benefits are capped to comply with Internal Revenue Code limitations. Ameren’s other postretirement plans are the Ameren Retiree Medical Plan and the Ameren Group Life Insurance Plan. Nonaffiliated Ameren companies do not participate in the Ameren Retirement Plan, the Ameren Supplemental Retirement Plan, the Ameren Retiree Medical Plan, or the Ameren Group Life Insurance Plan. On December 2, 2013, Ameren completed the divestiture of New AER to IPH. In accordance with the transaction agreement, Ameren retained the pension obligations as of December 2, 2013, associated with the current and former employees of New AER and its subsidiaries who were included in the Ameren Retirement Plan and the Ameren Supplemental Retirement Plan. Ameren also retained the postretirement benefit obligations associated with the employees of New AER and its subsidiaries who were eligible to retire at December 2, 2013, from the Ameren Retiree Medical Plan and the Ameren Group Life Insurance Plan. IPH assumed the existing pension and other postretirement benefit obligations associated with EEI’s current and former employees that are included in EEI’s single-employer pension and other postretirement plans. Coincident with Ameren’s divestiture of New AER, a significant number of employees left Ameren which required a measurement of Ameren’s pension and postretirement benefit plan assets and obligations as of December 2, 2013, based upon current market conditions. The reduction in obligations for the postretirement benefit plans and the accelerated recognition of gains previously recorded in accumulated other comprehensive income that had not previously been recognized through net periodic benefit cost for the pension and postretirement benefit plans resulted in a $19 million pretax curtailment gain, which was included in discontinued operations. Ameren completed another measurement as of December 31, 2013, as is its historical accounting practice, based upon the market conditions at the end of the year. Excluding the EEI plans, which were assumed by IPH during 2013, Ameren’s unfunded obligation under its pension and other postretirement benefit plans was $461 million and $1,143 million as of December 31, 2013, and December 31, 2012, respectively. These net liabilities are recorded in “Other current liabilities,” “Pension and other postretirement benefits,” and “Other assets” on Ameren’s consolidated balance sheet. The primary factors contributing to this unfunded obligation reduction during 2013 were a 75 basis point increase in the pension and other postretirement benefit plan discount rates used to determine the present value of the obligations, and asset returns being better than expected. The offset to the unfunded obligation reduction was primarily a reduction to “Regulatory assets” on Ameren’s consolidated balance sheet. The following table presents the net benefit liability recorded on the balance sheets of each of the Ameren Companies as of December 31, 2013, and 2012: Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . $ 461 191 198 $ 1,143 464 408 2013 2012 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. 126 Ameren recognizes the under-funded status of its pension and postretirement plans as a liability on its consolidated balance sheet, with offsetting entries to accumulated OCI and regulatory assets, in accordance with authoritative accounting guidance. The following table presents the funded status of our pension and postretirement benefit plans as of December 31, 2013, and 2012. It also provides the amounts included in regulatory assets and accumulated OCI at December 31, 2013, and 2012, that have not been recognized in net periodic benefit costs. 2013 2012 Pension Benefits(a) Postretirement Benefits(a) Pension Benefits(a) Postretirement Benefits(a) Accumulated benefit obligation at end of year . . . . . . . . . . . . . . . Change in benefit obligation: Net benefit obligation at beginning of year . . . . . . . . . . . . . . . . Service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Participant contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Curtailment gain(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlement(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Early retiree reinsurance program receipt . . . . . . . . . . . . . . . . . Federal subsidy on 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 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Federal subsidy on benefits paid . . . . . . . . . . . . . . . . . . . . . . . . Early retiree reinsurance program receipt . . . . . . . . . . . . . . . . . Participant contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of plan assets at end of year . . . . . . . . . . . . . . . . . . . . . Funded status – deficiency . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued benefit cost at December 31 . . . . . . . . . . . . . . . . . . . . . . Amounts recognized in the balance sheet consist of: Noncurrent asset(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current liability(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncurrent liability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net liability recognized . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amounts recognized in regulatory assets consist of: Net actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prior service cost (credit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amounts (pretax) recognized in accumulated OCI consist of: Net actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prior service cost (credit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ 3,698 4,051 91 163 - (207) - - (198) (b) (b) 3,900 3,127 376 156 (b) (b) - (198) 3,461 439 439 - 3 436 439 282 (7) 17 - $ $ $ $ $ $ (b) 1,157 22 46 16 (76) (3) (5) (64) - 3 1,096 938 156 25 3 - 16 (64) 1,074 22 22 (9) 1 30 22 (71) (20) (12) (1) $ $ $ $ $ $ 3,829 3,764 81 166 - 240 - - (200) (b) (b) 4,051 2,814 385 128 (b) (b) - (200) 3,127 924 924 - 3 921 924 699 (6) 65 (14) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 292 $ (104) $ 744 $ $ $ $ $ $ $ (b) 1,145 22 47 16 (10) - - (69) 2 4 1,157 836 104 45 4 2 16 (69) 938 219 219 - 2 217 219 103 (24) 5 (6) 78 Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) Not applicable. (c) Effective with the divestiture of New AER on December 2, 2013, the liability for active management employees of New AER and its subsidiaries not eligible to retire were neither transferred to IPH nor retained by Ameren, which resulted in a curtailment gain. See Note 16 – Divestiture Transactions and Discontinued Operations for further information on the divestiture. (d) Effective with the divestiture of New AER on December 2, 2013, the liability for active union employees of New AER and its subsidiaries not eligible to retire was transferred to IPH based on the assumption of the collective bargaining agreements in place, which resulted in a settlement. See Note 16 – Divestiture Transactions and Discontinued Operations for further information on the divestiture. Included in “Other assets” on Ameren’s consolidated balance sheet. Included in “Other current liabilities” on Ameren’s consolidated balance sheet. (e) (f) 127 The following table presents the assumptions used to determine our benefit obligations at December 31, 2013, and 2012: Discount rate at measurement date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in future compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (initial) Medical cost trend rate (ultimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Years to ultimate rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension Benefits 2012 2013 4.75% 4.00% 3.50 - - - 3.50 - - - Postretirement Benefits 2013 4.75% 3.50 5.00 5.00 - 2012 4.00% 3.50 5.00 5.00 - 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, pursuant to authoritative accounting guidance on the determination of discount rates used for defined benefit plan obligations. The settlement portfolio of bonds is selected from a pool of over 500 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 to the market value of the selected bonds. Funding Pension benefits are based on the employees’ years of service and compensation. Ameren’s pension plan is funded in compliance with income tax regulations and federal funding or regulatory requirements. As a result, Ameren expects to fund its pension plan at a level equal to the greater of the pension expense or the legally required minimum contribution. Considering its assumptions at December 31, 2013, its investment performance in 2013, and its pension funding policy, Ameren expects to make annual contributions of $20 million to $100 million in each of the next five years, with aggregate estimated contributions of $270 million. We expect Ameren Missouri’s and Ameren Illinois’ portion of the future funding requirements to be 52%, and 47%, respectively. These amounts are estimates. They 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 plan and to our postretirement plans during 2013, 2012, and 2011: Investment Strategy and Policies Ameren manages plan assets in accordance with the “prudent investor” guidelines contained in ERISA. The investment committee, to the extent authority is delegated to it by the finance committee of Ameren’s board of directors, implements investment strategy and asset allocation guidelines for the plan assets. The investment committee includes members of senior management. 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; second, to maximize total return on plan assets and minimize expense volatility consistent with its tolerance for risk. Ameren delegates investment management to specialists in each asset class. As appropriate, Ameren provides the 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 adjusted 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 plan assets and postretirement plan assets of 7.25% and 7.00%, respectively, in 2014. No plan assets are expected to be returned to Ameren during 2014. Pension Benefits 2012 2011 2013 Postretirement Benefits 2013 2012 2011 . . . $ Ameren Missouri Ameren Illinois . . . . . . . . . . . . . . . . . Other 60 $ 50 46 52 $ 46 30 Ameren(a) . . . . . . . . . 156 128 43 28 25 96 $ 10 $ 11 4 9 $ 35 1 25 45 9 118 2 129 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. 128 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, private equity), 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. The following table presents our target allocations for 2014 and our pension and postretirement plans’ asset categories as of December 31, 2013, and 2012. Asset Category Target Allocation 2014 Pension Plan: Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International and emerging markets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Real estate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Private equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Postretirement Plans: Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International Total equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a) Less than 1% of plan assets. 0 - 5 % 29 - 39 2 - 12 9 - 19 50 - 60 35 - 45 0 - 9 0 - 4 0 - 10 % 33 - 43 3 - 13 10 - 20 55 - 65 30 - 40 Percentage of Plan Assets at December 31, 2013 2% 36 8 14 58 36 4 (a) 100% 4% 41% 8% 14% 63% 33% 100% 2012 2% 34% 7% 13% 54% 39% 4% 1% 100% 4% 40% 8% 14% 62% 34% 100% In general, the United States large capitalization equity investments are passively managed or indexed, whereas the international, emerging markets, 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, emerging market 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. Ameren’s investment in private equity funds consists of 9 different limited partnerships, with invested capital ranging from $0.1 million to $5 million each, which invest primarily in a diversified number of small United States-based companies. No further commitments may be made to private equity investments without approval by the finance committee of the board of directors. Additionally, Ameren’s investment committee allows investment managers to use derivatives, such as index futures, exchange traded funds, 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, 2013. The fair value of an asset is the amount that would be received upon sale in an orderly transaction between market participants at the measurement date. Cash and cash equivalents have initial maturities of three months or less and are recorded at cost plus accrued interest. The carrying amounts of cash and cash equivalents approximate fair value because of the short-term nature of these instruments. Investments traded in active markets on national or international securities exchanges are valued at closing prices on the last business day on or before the measurement date. Securities traded in over-the-counter markets are valued based on quoted market prices, broker or dealer quotations, or alternative pricing sources with reasonable levels of price transparency. 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. The fair value of real estate is based on annual appraisal reports prepared by an independent real estate appraiser. 129 The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2013: Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . International and emerging markets . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Real estate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Private equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5 $ 39 $ 107 273 143 - - - - - - 1 (1) 1,162 - 372 860 149 256 27 - - - - Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 528 $ 2,865 $ Less: Medical benefit assets at December 31(a) . . . . . . . . . . . . . . . . . . Plus: Net receivables at December 31(b) . . . . . . . . . . . . . . . . . . . . . . . . Fair value of pension plans assets at year end . . . . . . . . . . . . . . . . . . . - - - - - - - - 131 15 - - 146 Total $ 44 1,269 273 515 860 149 256 27 131 15 1 (1) $ 3,539 (112) 34 $ 3,461 (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. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. The following table sets forth, by level within the fair value hierarchy discussed in Note 8 – Fair Value Measurements, the pension plan assets measured at fair value as of December 31, 2012: Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . International and emerging markets . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Real estate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Private equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1 $ 28 $ 83 235 134 - - - - - - - (1) 1,007 - 301 832 176 250 17 - - - - Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 452 $ 2,611 $ Less: Medical benefit assets at December 31(a) . . . . . . . . . . . . . . . . . . Plus: Net receivables at December 31(b) . . . . . . . . . . . . . . . . . . . . . . . . Fair value of pension plans assets at year end . . . . . . . . . . . . . . . . . . . - - - - - - - - 118 19 - - 137 Total $ 29 1,090 235 435 832 176 250 17 118 19 - (1) $ 3,200 (102) 29 $ 3,127 (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. (b) Receivables related to pending security sales, offset by payables related to pending security purchases. 130 The following table summarizes the changes in the fair value of the pension plan assets classified as Level 3 in the fair value hierarchy for each of the years ended December 31, 2013, and 2012: Beginning Balance at January 1, Actual Return on Plan Assets Related to Assets Still Held at the Reporting Date Actual Return on Plan Assets Related to Assets Sold During the Period Purchases, Sales, and Settlements, Net Net Transfers into (out of) of Level 3 Ending Balance at December 31, 2013: Real estate . . . . . . . . . . . . Private equity . . . . . . . . . . 2012: Real estate . . . . . . . . . . . . Private equity . . . . . . . . . . $ $ 118 19 108 23 $ 9 (9) $ 7 (7) $ $ - 11 - 8 $ $ 4 (6) 3 (5) $ $ - - - - $ $ 131 15 118 19 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 as of December 31, 2013: Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) $ 77 $ - $ Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . . . . . . . . . . . . . . . . . . . Asset-backed securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 297 77 39 - - - - - Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 490 $ Plus: Medical benefit assets at December 31(a) . . . . . . . . . . . . . . . . . . . Less: Net payables at December 31(b) . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of postretirement benefit plans assets at year end . . . . . . . . 101 - 96 89 103 72 10 40 511 $ - - - - - - - - - - Total $ 77 398 77 135 89 103 72 10 40 $ 1,001 112 (39) $ 1,074 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by Medicare, interest receivables, and receivables related to pending security sales. 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 as of December 31, 2012: Quoted Prices in Active Markets for Identified Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Other Unobservable Inputs (Level 3) Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity securities: U.S. large capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. small and mid-capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt securities: Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Municipal bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U.S. treasury and agency securities . . . . . . . . . . . . . . . . . . . . . . . . . . . Asset-backed securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 83 $ 245 66 45 - - - - - $ - 88 - 69 88 91 67 18 22 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 439 $ 443 $ - - - - - - - - - - Plus: Medical benefit assets at December 31(a) Less: Net payables at December 31(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of postretirement benefit plans assets at year end . . . . . . . . . . Total $ 83 333 66 114 88 91 67 18 22 $ 882 102 (46) $ 938 (a) Medical benefit (health and welfare) component for 401(h) accounts to fund a portion of the postretirement obligation. These 401(h) assets are included in the pension plan assets shown above. (b) Payables related to pending security purchases, offset by Medicare, interest receivables, and receivables related to pending security sales. 131 Net Periodic Benefit Cost The following table presents the components of the net periodic benefit cost of our pension and postretirement benefit plans during 2013, 2012, and 2011: Pension Benefits Postretirement Benefits Ameren(a) Ameren(a) 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of: Transition obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prior service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Curtailment gain . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 91 163 (218) - (2) 87 (12) Net periodic benefit cost(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 109 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of: Transition obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prior service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 81 166 (208) - (3) 75 Net periodic benefit cost(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 111 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of: Transition obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prior service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net periodic benefit cost(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 73 175 (211) - (1) 41 77 $ 22 46 (62) $ $ - (6) 8 (7) 1 22 47 (56) 2 (6) 5 $ 14 $ 20 54 (50) 2 (6) 3 $ 23 Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) The net periodic benefit cost includes a $6 million and a $7 million net gain for pension benefits and postretirement benefits, respectively, which was included in “Income (loss) from discontinued operations, net of taxes” on Ameren’s consolidated statement of income (loss). This net gain includes the curtailment gain recognized in 2013 as a result of a significant reduction in employees as of the December 2, 2013 closing date of the New AER divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. (c) The net periodic benefit cost includes $9 million and $- million in total net costs for pension benefits and postretirement benefits, respectively, for 2012 which were included in “Income (loss) from discontinued operations, net of taxes” on Ameren’s consolidated statement of income (loss). The net periodic benefit cost includes $7 million and $- million in total net costs for pension benefits and postretirement benefits, respectively, for 2011 which were included in “Income (loss) from discontinued operations, net of taxes” on Ameren’s consolidated statement of income (loss). See Note 16 – Divestiture Transactions and Discontinued Operations for additional information on the divestiture. The current year expected return on plan assets is determined primarily by adjusting the prior-year market-related asset value for current year contributions, disbursements, and expected return, plus 25% of the actual return in excess of (or less than) expected return for the four prior years. The estimated amounts that will be amortized from regulatory assets and accumulated OCI into net periodic benefit cost in 2014 are as follows: Regulatory assets: Pension Benefits Postretirement Benefits Ameren(a) Ameren(a) Prior service cost (credit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net actuarial loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated OCI: Net actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (1) 60 1 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 60 $ (4) 9 (2) $ 3 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. 132 Prior service cost is amortized on a straight-line basis over the average future service of active participants benefiting under the plan amendment. The net actuarial (gain) loss subject to amortization is amortized on a straight-line basis over 10 years. 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 and included in continuing operations for the years ended December 31, 2013, 2012, and 2011: Pension Costs Postretirement Costs 2013 2012 2011 2013 2012 2011 Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 69 41 5 115 $ 63 37 2 102 $ 51 16 3 70 $ 8 - - 8 $ 10 4 - 14 $ 11 11 1 23 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. The expected pension and postretirement benefit payments from qualified trust and company funds and the federal subsidy for postretirement benefits related to prescription drug benefits, which reflect expected future service, as of December 31, 2013, are as follows: 2014 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2015 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2016 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 - 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension Benefits Postretirement Benefits Paid from Qualified Trust $ 247 249 255 260 264 1,342 Paid from Company Funds $ 3 3 3 3 3 14 Paid from Qualified Trust $ 61 63 66 69 72 394 Paid from Company Funds Federal Subsidy $ 2 2 2 2 2 12 $ 3 4 4 4 4 19 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, 2013, 2012, and 2011: Pension Benefits Postretirement Benefits 2013 2012 2011 2013 2012 2011 Discount rate at measurement date . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in future compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (initial) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medical cost trend rate (ultimate) . . . . . . . . . . . . . . . . . . . . . . . . . . . . Years to ultimate rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.00% 7.50 3.50 - - - 4.50% 7.75 3.50 - - - 5.25% 8.00 3.50 - - - 4.00% 7.25 3.50 5.00 5.00 - 4.50% 7.50 3.50 5.50 5.00 1 year 5.25% 7.75 3.50 6.00 5.00 2 years The table below reflects the sensitivity of Ameren’s plans to potential changes in key assumptions: Pension Benefits Postretirement Benefits Service Cost and Interest Cost Projected Benefit Obligation Service Cost and Interest Cost Postretirement Benefit Obligation 0.25% decrease in discount rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.25% increase in salary scale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.00% increase in annual medical trend . . . . . . . . . . . . . . . . . . . . . . . . . . 1.00% decrease in annual medical trend . . . . . . . . . . . . . . . . . . . . . . . . . $ $ (2) 2 - - $ 109 17 - - $ - - 2 (2) 32 - 40 (37) 133 Other Ameren sponsors a 401(k) plan for eligible employees. The Ameren 401(k) plan covered all eligible employees at December 31, 2013. The plan allowed employees to contribute a portion of their compensation in accordance with specific guidelines. Ameren matched 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 the continuing operations for each of the Ameren Companies for the years ended December 31, 2013, 2012, and 2011: Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2013 2012 2011 $ 16 10 1 27 $ 16 9 1 26 $ 16 8 1 25 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries. NOTE 12 – STOCK-BASED COMPENSATION Ameren’s long-term incentive plan available for eligible employees is the shareholder-approved 2006 Omnibus Incentive Compensation Plan (2006 Plan), which became effective May 2, 2006. The 2006 Plan provides for a maximum of 4 million common shares to be available for grant to eligible employees and directors. The 2006 Plan 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. A summary of nonvested shares at December 31, 2013, and changes during the year ended December 31, 2013, under the 2006 Plan are presented below: Nonvested at January 1, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Granted(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unearned or forfeited(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Earned and vested(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Performance Share Units Share Units 1,192,487 840,482 (29,730) (784,695) Weighted-average Fair Value per Unit $ 33.56 31.19 31.93 31.60 Nonvested at December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,218,544 $ 33.23 (a) (b) (c) Includes performance share units (share units) granted to certain executive and nonexecutive officers and other eligible employees in 2013 under the 2006 Plan. Includes share units granted in 2011 that were not earned based on performance provisions of the award grants. Includes share units granted in 2011 that vested as of December 31, 2013, that were earned pursuant to the provisions of the award grants. Also includes share units that vested due to attainment of retirement eligibility by certain employees and certain employees whose employment terminated on December 2, 2013, with the divestiture of New AER. Actual shares issued for retirement-eligible employees and former New AER subsidiaries’ employees will vary depending on actual performance over the three-year measurement period. Ameren recorded compensation expense of $20 million, $22 million, and $13 million for the years ended December 31, 2013, 2012, and 2011, respectively, and a related tax benefit of $8 million, $8 million and $5 million for the years ended December 31, 2013, 2012, and 2011, respectively. Ameren settled performance share units and restricted shares of $11 million, $11 million, and $4 million for the years ended December 31, 2013, 2012, and 2011. All outstanding restricted shares vested as of the end of 2011. There were no significant compensation costs capitalized related to the performance share units during the years ended December 31, 2013, 2012, and 2011. As of December 31, 2013, total compensation cost of $20 million related to nonvested awards not yet recognized is expected to be recognized over a weighted-average period of 20 months. Performance Share Units Performance share units have been granted under the 2006 Plan. A 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 performance or market conditions have been met and the individual remains employed by Ameren. 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. The fair value of each share unit awarded in January 2013 under the 2006 Plan was determined to be $31.19. That amount was based on Ameren’s closing common share price of $30.72 at December 31, 2012, and lattice simulations. Lattice simulations are used to estimate expected share payout based on Ameren’s total shareholder return for a three-year performance period relative to the 134 designated peer group beginning January 1, 2013. The simulations can produce a greater fair value for the share unit than the applicable closing common share price because they include the weighted payout scenarios in which an increase in the share price has occurred. The significant assumptions used to calculate fair value also included a three-year risk-free rate of 0.36%, volatility of 12% to 21% for the peer group, and Ameren’s attainment of a three-year average earnings per share threshold during the performance period. The fair value of each share unit awarded in January 2012 under the 2006 Plan was determined to be $35.68. That amount was based on Ameren’s closing common NOTE 13 – INCOME TAXES share price of $33.13 at December 31, 2011, and lattice simulations. Lattice simulations are used to estimate expected share payout based on Ameren’s total shareholder return for a three-year performance period relative to the designated peer group beginning January 1, 2012. The simulations can produce a greater fair value for the share unit than the applicable closing common share price because they include the weighted payout scenarios in which an increase in the share price has occurred. The significant assumptions used to calculate fair value also included a three-year risk-free rate of 0.41%, volatility of 17% to 31% for the peer group, and Ameren’s attainment of a three-year average earnings per share threshold during the performance period. The following table presents the principal reasons why the effective income tax rate differed from the statutory federal income tax rate for the years ended December 31, 2013, 2012, and 2011: Ameren Missouri Ameren Illinois Ameren 2013 Statutory federal income tax rate: Increases (decreases) from: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation differences . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of investment tax credit State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other permanent items(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Statutory federal income tax rate: Increases (decreases) from: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation differences . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of investment tax credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Reserve for uncertain tax positions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other permanent items(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 Statutory federal income tax rate: Increases (decreases) from: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation differences . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of investment tax credit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Reserve for uncertain tax positions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tax credits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other permanent items(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Effective income tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35% - (1) 3 1 38% 35% (1) (1) 3 1 - 37% 35% (2) (1) 3 - - 1 36% 35% (1) - 6 - 40% 35% - (1) 6 - - 40% 35% - (1) 5 - - - 35% - (1) 4 - 38% 35% (1) (1) 5 - (1) 37% 35% (1) (1) 4 1 (1) - 39% 37% (a) Permanent items are treated differently for book and tax purposes and primarily include non-taxable income related to company-owned life insurance and deductions related to dividends on DRPlus and the 401(k) plan for Ameren, as well as nondeductible expenses related to lobbying and stock issuance costs for Ameren Missouri. 135 The following table presents the components of income tax expense (benefit) for the years ended December 31, 2013, 2012, and 2011: Ameren Missouri Ameren Illinois Other Ameren(a) 2013 Current taxes: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Federal State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred investment tax credits, amortization . . . . . . . . . . . . . . . . . . Total income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 Current taxes: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Federal State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred investment tax credits, amortization . . . . . . . . . . . . . . . . . . Total income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 Current taxes: Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred taxes: $ $ $ $ $ Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred investment tax credits, amortization . . . . . . . . . . . . . . . . . . Total income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . $ 136 41 64 6 (5) 242 (25) (10) 248 44 (5) 252 3 2 129 31 (4) 161 $ $ $ $ $ $ (15) 21 99 6 (1) 110 (7) (3) 76 30 (2) 94 (24) (4) 123 34 (2) 127 $ $ $ $ $ $ (239)(b) $ (43)(b) 205(b) 36(b) - (41) $ $ 72 23 (120) (14) - (39) $ 15 - (39) (10) - (34) $ $ (118) 19 368 48 (6) 311 40 10 204 60 (7) 307 (6) (2) 213 55 (6) 254 Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (a) (b) These amounts are substantially related to the reversal of unrecognized tax benefits as a result of new IRS guidance related to the deductibility of expenditures to maintain, replace or improve steam or electric power generation property, along with casualty loss deductions for storm damage. They also reflect the increase in deferred tax expense due to available net operating losses. The Illinois corporate income tax rate increased from 7.3% to 9.5%, as of January 2011. The tax rate is scheduled to decrease to 7.75% in 2015, and it is scheduled to return to 7.3% in 2025. This corporate income tax rate increase in Illinois increased current income tax expense in 2011 by $6 million and $4 million for Ameren and Ameren Illinois, respectively. As a result of this corporate income tax rate increase, accumulated deferred tax balances were revalued, resulting in a decrease in deferred tax expense of $2 million and $3 million for Ameren and Ameren Illinois, respectively, in 2011. The following table presents the deferred tax assets and deferred tax liabilities recorded as a result of temporary differences at December 31, 2013, and 2012: Ameren Missouri Ameren Illinois Other Ameren(a) 2013 Accumulated deferred income taxes, net liability (asset): Plant related . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred employee benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . . Purchase accounting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ARO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(b)(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total net accumulated deferred income tax liabilities (assets)(d) . . . . 2012 Accumulated deferred income taxes, net liability (asset): Plant related . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred employee benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . . Purchase accounting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ARO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other(b) $ $ $ Total net accumulated deferred income tax liabilities (assets)(e) . . . . $ 2,513 74 (74) - (7) (17) 2,489 2,385 73 (84) - (7) 50 2,417 $ $ $ $ 1,243 2 (85) (27) 1 (63) 1,071 1,145 - (102) (27) 1 (77) 940 $ $ $ $ 13 - (114) (1) - (398) (500) 20 - (137) (1) - (223) (341) $ $ $ $ 3,769 76 (273) (28) (6) (478) 3,060 3,550 73 (323) (28) (6) (250) 3,016 136 (a) (b) (c) (d) (e) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Includes deferred tax assets related to net operating loss and tax credit carryforwards detailed in the table below. Includes total valuation allowances for Ameren, Ameren Missouri and Ameren Illinois of $7 million, $1 million, and $1 million, respectively, as of December 31, 2013. The state valuation allowances are shown in the table below. Includes $20 million recorded in “Other current assets” on Ameren Missouri’s balance sheet as of December 31, 2013. Includes $26 million recorded in “Other current assets” on Ameren Missouri’s balance sheet as of December 31, 2012. The following table presents the components of deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2013: Ameren Missouri Ameren Illinois Other Ameren(a) Net operating loss carryforwards: Federal(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total net operating loss carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . Tax credit carryforwards: Federal(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State valuation allowance(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total tax credit carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ 61 3 64 12 1 (1) 12 $ $ $ $ 84 11 95 - 1 (1) - $ $ $ $ 215 34 249 76 32 (2) 106 $ $ $ 360 48 408 88 34 (4) $ 118 Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) These will begin to expire in 2028. (c) These will begin to expire in 2017. (d) These will begin to expire in 2029. (e) These will begin to expire in 2014. (f) This balance increased by $2 million, $- million and $- million for Ameren, Ameren Missouri and Ameren Illinois, respectively, during 2013. The following table presents the components of deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2012: Ameren Missouri Ameren Illinois Other Ameren(a) Net operating loss carryforwards: Federal(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total net operating loss carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . Tax credit carryforwards: Federal(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State valuation allowance(f) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total tax credit carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ 61 3 64 11 1 (1) 11 $ $ $ $ 61 11 72 - 1 (1) - $ $ $ $ 51 13 64 75 23 - 98 $ $ $ 173 27 200 86 25 (2) $ 109 Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) These will begin to expire in 2028 (c) These will begin to expire in 2017. (d) These will begin to expire in 2029. (e) These began to expire in 2013. (f) This balance increased by $1 million, $- million and $1 million for Ameren, Ameren Missouri and Ameren Illinois, respectively, during 2012. 137 Uncertain Tax Positions A reconciliation of the change in the unrecognized tax benefit balance during the years ended December 31, 2011, 2012, and 2013, is as follows: Ameren Missouri Ameren Illinois Other Ameren(a) Unrecognized tax benefits – January 1, 2011 . . . . . . . . . . . . . . . . . . . . Increases based on tax positions prior to 2011 . . . . . . . . . . . . . . . . Decreases based on tax positions prior to 2011 . . . . . . . . . . . . . . . . Increases based on tax positions related to 2011 . . . . . . . . . . . . . . . Changes related to settlements with taxing authorities . . . . . . . . . . . Decreases related to the lapse of statute of limitations . . . . . . . . . . . Unrecognized tax benefits – December 31, 2011 . . . . . . . . . . . . . . . . . Increases based on tax positions prior to 2012 . . . . . . . . . . . . . . . . Decreases based on tax positions prior to 2012 . . . . . . . . . . . . . . . . Increases (decreases) based on tax positions related to 2012 . . . . . Changes related to settlements with taxing authorities . . . . . . . . . . . Decreases related to the lapse of statute of limitations . . . . . . . . . . . Unrecognized tax benefits – December 31, 2012 . . . . . . . . . . . . . . . . . Increases based on tax positions prior to 2013 . . . . . . . . . . . . . . . . Decreases based on tax positions prior to 2013 . . . . . . . . . . . . . . . . Increases based on tax positions related to 2013 . . . . . . . . . . . . . . . Changes related to settlements with taxing authorities . . . . . . . . . . . Increases related to the lapse of statute of limitations . . . . . . . . . . . Unrecognized tax benefits (detriments) – December 31, 2013 . . . . . . . Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2011 . . . . . . . . . . . . . . . . . . . Total unrecognized tax benefits (detriments) that, if recognized, would affect the effective tax rates as of December 31, 2012 . . . . . . . . . . . Total unrecognized tax benefits that, if recognized, would affect the effective tax rates as of December 31, 2013 . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ $ 164 15 (63) 13 (5) - 124 4 (7) 15 - - 136 - (122) 16 - 1 31 1 3 3 $ $ $ $ $ $ $ 56 - (41) - (4) - 11 - (1) 3 - - 13 2 (16) - - - (1) - (1) - $ $ $ $ $ $ $ 26 7 (21) 4 (1) (2) 13 1 (5) (1) - (1) 7 5 (5) 53(b) - - 60 - (1) 51(b) $ $ $ $ $ $ $ 246 22 (125) 17 (10) (2) 148 5 (13) 17 - (1) 156 7 (143) 69 - 1 90 1 1 54 Includes amounts for Ameren registrant and nonregistrant subsidiaries. (a) (b) Primarily due to tax positions relating to the New AER divestiture. The income statement impact of this unrecognized tax benefit was included in “Income (loss) from discontinued operations, net of taxes” on Ameren’s consolidated statement of income (loss). See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. The Ameren Companies recognize interest charges (income) and penalties accrued on tax liabilities on a pretax basis as interest charges (income) or miscellaneous expense, respectively, in the statements of income. A reconciliation of the change in the liability for interest on unrecognized tax benefits during the years ended December 31, 2011, 2012, and 2013, is as follows: Ameren Missouri Ameren Illinois Other Liability for interest – January 1, 2011 . . . . . . . . . . . . . . . . . . . . . . . . . Interest income for 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest payment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liability for interest – December 31, 2011 . . . . . . . . . . . . . . . . . . . . . . Interest charges (income) for 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . Liability for interest – December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . Interest charges (income) for 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . Liability for interest – December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ 10 (3) (1) 6 2 8 (8) - $ $ $ $ 2 (1) - 1 - 1 (1) - $ $ $ $ 5 (7) - (2) (1) (3) 4 1 Ameren(a) $ 17 (11) (1) 5 1 6 (5) 1 $ $ $ (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. As of December 31, 2011, 2012, and 2013, the Ameren Companies have accrued no amount for penalties with respect to unrecognized tax benefits. In 2011, a final settlement for the years 2005 and 2006 was reached with the IRS. It resulted in a reduction in uncertain tax liabilities of $39 million, $17 million and $12 million for Ameren, Ameren Missouri and Ameren Illinois, respectively. Ameren’s federal income tax returns for the years 2007 through 2011 are before the Appeals Office of the IRS. Ameren’s federal income tax return for the year 2012 is currently under examination. 138 It is reasonably possible that a settlement will be reached with the Appeals Office of the IRS in the next twelve months for the years 2007 through 2011. This settlement, primarily related to uncertain tax positions for capitalization versus currently deductible repair expense and research deductions, is expected to result in a decrease in uncertain tax benefits of approximately $20 million and $13 million for Ameren and Ameren Missouri, respectively. In addition, it is reasonably possible that other events will occur during the next twelve months that would cause the total amount of unrecognized tax benefits for the Ameren Companies to increase or decrease. However, the Ameren Companies do not believe any such increases or decreases, including the decrease from the reasonably possible IRS Appeals Office settlement discussed above, would be material to their results of operations, financial position, or liquidity. In 2013, unrecognized tax benefits related to the deductibility of expenditures to maintain, replace, or improve steam or electric power generation property, along with casualty loss deductions for storm damage, were reduced by $103 million, $95 million and $5 million for Ameren, Ameren Missouri and Ameren Illinois, respectively. This reduction in unrecognized tax benefits did not impact overall income tax expense for the Ameren Companies. However, the liability for interest related to these unrecognized tax benefits has been released. In 2013, Ameren adopted an accounting method change as a result of the recent guidance issued by the IRS, establishing new rules for the amount and timing of the deductions to maintain, replace or improve generation property. In 2014, Ameren expects to adopt an accounting method change as a result of the recent guidance establishing new rules for the amount and timing of casualty loss deductions for storm damage. State income tax returns are generally subject to examination for a period of three years after filing of the return. The state impact of any federal changes remains subject to examination by various states for a period of up to one year after formal notification to the states. The Ameren Companies do not currently have material state 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, using the weighted-average cost of capital included in each of the electric rate orders in effect before the tax position was resolved, of the difference between the uncertain income 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 and then will be amortized over three years beginning on the effective date of new rates established in the next electric rate case. NOTE 14 – RELATED PARTY TRANSACTIONS The Ameren Companies have engaged in, and may in the future engage in, affiliate transactions in the normal course of business. These transactions primarily consist of natural gas and power purchases and sales, services received or rendered, and borrowings and lendings. Transactions between affiliates are reported as intercompany transactions on their financial statements, but are eliminated in consolidation for Ameren’s financial statements. Below are the material related party agreements. Electric Power Supply Agreements Capacity Supply Agreements Ameren Illinois, as an electric load-serving entity, must acquire capacity sufficient to meet its obligations to customers. In 2010, Ameren Illinois used an RFP process, administered by the IPA, to contract capacity for the period from June 1, 2010, through May 31, 2013. As a winning supplier in this process, in April 2010, Ameren Missouri contracted to supply a portion of Ameren Illinois’ capacity requirements for less than $1 million for the period from June 1, 2010, through May 31, 2013. In 2012, Ameren Illinois used an RFP process, administered by the IPA, to contract capacity for the period from June 1, 2012, through May 31, 2015. As a winning supplier in this process, in April 2012, Ameren Missouri contracted to supply a portion of Ameren Illinois’ capacity requirements for $1 million and $3 million for the 12 months ending May 31, 2014, and 2015, respectively. Energy Swaps and Energy Products Ameren Illinois, as an electric load-serving entity, must acquire energy sufficient to meet its obligations to customers. In 2011, Ameren Illinois used an RFP process, administered by the IPA, to procure energy products that will settle physically from June 1, 2011, through May 31, 2014. Ameren Missouri was among the winning suppliers in the energy product RFP process. In May 2011, Ameren Missouri and Ameren Illinois entered into energy product agreements by which Ameren Missouri agreed to sell and Ameren Illinois agreed to purchase approximately 16,800 megawatthours at approximately $37 per megawatthour during the 12 months ending May 31, 2012, approximately 40,800 megawatthours at approximately $29 per megawatthour during the 12 months ending May 31, 2013, and approximately 40,800 megawatthours at approximately $28 per megawatthour during the 12 months ending May 31, 2014. The energy product agreements between Ameren Missouri and Ameren Illinois for the periods ending May 31, 2012, and May 31, 2013, were for off-peak hours only. 139 Interconnection and Transmission Agreements Ameren Missouri and Ameren Illinois are parties to an interconnection agreement for the use of their respective transmission lines and other facilities for the distribution of power. These agreements have no contractual expiration date, but may be terminated by either party with three years’ notice. Joint Ownership Agreement ATXI and Ameren Illinois have a joint ownership agreement to construct, own, operate, and maintain certain electric transmission assets in Illinois. Under the terms of this agreement, Ameren Illinois and ATXI are responsible for their applicable share of all costs related to the construction, operation, and maintenance of electric transmission systems. Currently, there are no construction projects or joint ownership of existing assets under this agreement. In January 2011, ATXI repaid advances for the construction of transmission assets to Ameren Illinois in the amount of $52 million, including $3 million of accrued interest. In April 2011, ATXI transferred, at cost, all of ATXI’s construction work in progress assets related to a transmission line to Ameren Illinois for $20 million. 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 shared services support agreement can be terminated with respect to a particular affiliate by the mutual agreement of Ameren Services and that affiliate or by either Ameren Services or that affiliate with 60 days’ notice before the end of a calendar year. In addition, Ameren Missouri and Ameren Illinois provide affiliates, primarily Ameren Services, with access to their facilities for administrative purposes. The cost of the rent and facility services are based on, or are an allocation of, actual costs incurred. Separately, Ameren Missouri and Ameren Illinois provide storm-related and miscellaneous support services to each other on an as-needed basis. Transmission Services Ameren Illinois must take transmission service from MISO for the retail load it serves in the AMIL pricing zone. ATXI is one of the transmission owners in the AMIL pricing zone. Accordingly ATXI receives transmission payments from Ameren Illinois through the MISO billing process. Money Pool See Note 4 – Short-term Debt and Liquidity and Note 5 – Long-term Debt and Equity Financings for a discussion of affiliate borrowing arrangements. Collateral Postings Under the terms of the Illinois power procurement 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, meaning that only the suppliers would 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, 2013, and 2012, there were no collateral postings required of Ameren Missouri related to the Illinois power procurement agreements. The following table presents the impact on Ameren Missouri and Ameren Illinois of related party transactions for the years ended December 31, 2013, 2012, and 2011. It is based primarily on the agreements discussed above and the money pool arrangements discussed in Note 4 – Short-term Debt and Liquidity. Agreement Ameren Missouri power supply agreements with Ameren Illinois Ameren Missouri and Ameren Illinois rent and facility services Ameren Missouri and Ameren Illinois miscellaneous support services Total Operating Revenues Ameren Missouri Ameren Illinois $ $ 3 (b) 2 21 19 16 1 1 5 25 20 23 $ $ (a) (a) (a) 1 1 2 3 (b) 1 4 1 3 2013 2012 2011 2013 2012 2011 2013 2012 2011 2013 2012 2011 Income Statement Line Item Operating Revenues Operating Revenues Operating Revenues 140 Agreement Income Statement Line Item Ameren Illinois power supply agreements with Ameren Missouri Ameren Illinois transmission services with ATXI Total Purchased Power Ameren Services support services agreement Insurance premiums(c) Total Other Operations and Maintenance Expenses Money pool borrowings (advances) Purchased Power Purchased Power Other Operations and Maintenance Other Operations and Maintenance Interest (Charges) Income Ameren Missouri Ameren Illinois $ $ $ $ $ $ $ $ $ $ (a) (a) (a) (a) (a) (a) (a) (a) (a) 116 106 114 (b) (b) (b) 116 106 114 (b) (b) - 3 (b) 2 2 3 3 5 3 5 93 88 87 (a) (a) (a) 93 88 87 (b) (b) - 2013 2012 2011 2013 2012 2011 2013 2012 2011 2013 2012 2011 2013 2012 2011 2013 2012 2011 2013 2012 2011 (a) Not applicable. (b) Amount less than $1 million. (c) Represents insurance premiums paid to Energy Risk Assurance Company, an affiliate for replacement power, property damage, and terrorism coverage. NOTE 15 – 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 these 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 10 – Callaway Energy Center, Note 14 – Related Party Transactions, and Note 16 – Divestiture Transactions and Discontinued Operations in this report. Callaway Energy Center The following table presents insurance coverage at Ameren Missouri’s Callaway energy center at December 31, 2013. The property coverage and the nuclear liability coverage must be renewed on April 1 and January 1, respectively, of each year. Type and Source of Coverage Public liability and nuclear worker liability: American Nuclear Insurers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pool participation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Property damage: Nuclear Electric Insurance Limited . . . . . . . . . . . . . . . . . . . . . . . . European Mutual Association for Nuclear Insurance . . . . . . . . . . . Replacement power: Nuclear Electric Insurance Limited . . . . . . . . . . . . . . . . . . . . . . . . Missouri Energy Risk Assurance Company . . . . . . . . . . . . . . . . . . Maximum Coverages Maximum Assessments $ $ $ $ $ $ 375 13,241(a) 13,616(c) 2,250(d) 500(f) 2,750 490(g) 64(h) $ - 128(b) $ 128 $ $ $ $ 23(e) - 23 9(e) - (a) Provided through mandatory participation in an industrywide retrospective premium assessment program. (b) Retrospective premium under the Price-Anderson Act. This is subject to retrospective assessment with respect to a covered loss in excess of $375 million in the event of an incident at any licensed United States commercial reactor, payable at $19 million per year. 141 (c) Limit of liability for each incident under the Price-Anderson Act liability provisions of the Atomic Energy Act of 1954, as amended. A company could be assessed up to $128 million per incident for each licensed reactor it operates with a maximum of $19 million per incident to be paid in a calendar year for each reactor. This limit is subject to change to account for the effects of inflation and changes in the number of licensed reactors. (d) Nuclear Electric Insurance Limited provides $2.25 billion in property damage, decontamination, and premature decommissioning insurance. There is a $1.7 billion sublimit for non-radiation events, of which the top $200 million is a shared limit with other generators purchasing this coverage and includes one free reinstatement. (e) All Nuclear Electric Insurance Limited insured plants could be subject to assessments should losses exceed the accumulated funds from (f) Nuclear Electric Insurance Limited. European Mutual Association for Nuclear Insurance provides $500 million in excess of the $2.25 billion property coverage and $1.7 billion non- radiation coverage. (g) Provides replacement power cost insurance in the event of a prolonged accidental outage at our nuclear energy center. Weekly indemnity up to $4.5 million for 52 weeks, which commences after the first eight 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. Effective April 1, 2013, non-radiation events are sub-limited to $327.6 million. (h) Provides replacement power cost insurance in the event of a prolonged accidental outage at our nuclear energy center. The coverage commences after the first 52 weeks of insurance coverage from Nuclear Electric Insurance Limited and is a weekly indemnity of $900,000 for 71 weeks in excess of the $3.6 million per week set forth above. Missouri Energy Risk Assurance Company LLC is an affiliate and has reinsured this coverage with third-party insurance companies. See Note 14 – Related Party Transactions for more information on this affiliate transaction. 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 five-year inflationary adjustment was effective September 10, 2013. Owners of a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by the Price-Anderson Act. Losses resulting from terrorist attacks are covered under Nuclear Electric Insurance Limited’s policies, subject to an industrywide aggregate policy limit of $3.24 billion within a 12-month period for coverage for such terrorist acts. 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. Leases We lease various facilities, office equipment, plant equipment, and rail cars under capital and operating leases. The following table presents our lease obligations at December 31, 2013: Total 2014 2015 2016 2017 2018 After 5 Years Ameren:(a) Minimum capital lease payments(b) . . . . . . . . . . . . . . . . . . . . . . . . . . Less amount representing interest . . . . . . . . . . . . . . . . . . . . . . . . . . Present value of minimum capital lease payments . . . . . . . . . . . . . . Operating leases(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total lease obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Minimum capital lease payments(b) . . . . . . . . . . . . . . . . . . . . . . . . . . Less amount representing interest . . . . . . . . . . . . . . . . . . . . . . . . . . Present value of minimum capital lease payments . . . . . . . . . . . . . . Operating leases(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total lease obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Operating leases(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ $ 556 257 299 117 416 556 257 299 106 405 7 $ $ $ $ $ $ $ 32 27 5 14 19 32 27 5 11 16 2 $ $ $ $ $ $ $ 33 27 6 13 19 33 27 6 11 17 1 $ $ $ $ $ $ $ 33 27 6 13 19 33 27 6 11 17 1 $ $ $ $ $ $ $ 33 27 6 13 19 33 27 6 12 18 1 $ $ $ $ $ $ $ 32 26 6 13 19 32 26 6 11 17 $ $ 393 123 270 51 $ 321 $ $ 393 123 270 50 $ 320 1 $ 1 Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (a) (b) See Properties under Part I, Item 2, and Note 3 – Property and Plant, Net, of this report for additional information. (c) Amounts related to certain land-related leases have indefinite payment periods. The annual obligation of $2 million, $1 million and $1 million for Ameren, Ameren Missouri and Ameren Illinois for these items is included in the 2014 through 2018 columns, respectively. 142 The following table presents total rental expense, included in operating expenses, for the years ended December 31, 2013, 2012, and 2011: Ameren(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 32 29 21 $ 33 29 19 $ 36 29 17 2013 2012 2011 (a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. Other Obligations To supply a portion of the fuel requirements of our energy centers, we have entered into various long-term commitments for the procurement of coal, natural gas, nuclear fuel, and methane gas. We also have entered into various long-term commitments for purchased power and natural gas for distribution. The table below presents our estimated commitments at December 31, 2013. Ameren’s and Ameren Missouri’s purchased power obligations include a 102-megawatt power purchase agreement with a wind farm operator that expires in 2024. Ameren’s and Ameren Illinois’ purchased power obligations include the Ameren Illinois power purchase agreements entered into as part of the IPA-administered power procurement process. Included in the Other column are minimum purchase commitments under contracts for equipment, design and construction, and meter reading services at December 31, 2013. Ameren’s and Ameren Illinois’ Other column also include obligations related to IEIMA. In addition, the Other column includes Ameren’s and Ameren Missouri’s obligations related to energy efficiency programs under the MEEIA as approved by the MoPSC’s December 2012 electric rate order. Ameren Missouri expects to incur $48 million in 2014 and $64 million in 2015 for these energy efficiency programs. See Note 2 – Rate and Regulatory Matters for additional information about the IEIMA and MEEIA. Coal Natural Gas(a) Nuclear Fuel Purchased Power(b) Methane Gas Other Total Ameren:(c) 2014 . . . . . . . . . . . . . . . . . . . . . 2015 . . . . . . . . . . . . . . . . . . . . . 2016 . . . . . . . . . . . . . . . . . . . . . 2017 . . . . . . . . . . . . . . . . . . . . . 2018 . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . $ 620 642 664 676 120 125 Total . . . . . . . . . . . . . . . . . . . . . $ 2,847 Ameren Missouri: 2014 . . . . . . . . . . . . . . . . . . . . . 2015 . . . . . . . . . . . . . . . . . . . . . 2016 . . . . . . . . . . . . . . . . . . . . . 2017 . . . . . . . . . . . . . . . . . . . . . 2018 . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . $ 620 642 664 676 120 125 Total . . . . . . . . . . . . . . . . . . . . . $ 2,847 Ameren Illinois: 2014 . . . . . . . . . . . . . . . . . . . . . 2015 . . . . . . . . . . . . . . . . . . . . . 2016 . . . . . . . . . . . . . . . . . . . . . 2017 . . . . . . . . . . . . . . . . . . . . . 2018 . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . $ Total . . . . . . . . . . . . . . . . . . . . . $ - - - - - - - $ $ $ $ $ $ 323 179 90 45 28 82 747 62 32 19 11 8 28 160 261 147 71 34 20 54 587 $ $ $ $ $ $ 64 63 81 58 57 158 481 64 63 81 58 57 158 481 - - - - - - - $ $ $ $ $ $ 308 164 78 55 52 635 $ 1,292 $ $ $ 19 19 19 19 19 110 205 289 145 59 36 33 525 $ 1,087 $ 3 4 4 4 5 91 111 3 4 4 4 5 91 111 - - - - - - - $ $ $ $ $ $ 201 143 76 50 51 350 871 127 101 40 26 27 183 504 23 24 24 24 24 167 286 $ 1,519 1,195 993 888 313 1,441 $ 6,349 $ 895 861 827 794 236 695 $ 4,308 $ 573 316 154 94 77 746 $ 1,960 Includes amounts for generation and for distribution. (a) (b) The purchased power amounts for Ameren and Ameren Illinois include 20-year agreements for renewable energy credits that were entered into in December 2010 with various renewable energy suppliers. The agreements contain a provision that allows Ameren Illinois to reduce the quantity purchased in the event that Ameren Illinois would not be able to recover the costs associated with the renewable energy credits. Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations. (c) Ameren Illinois has entered into an agreement, through a process administered by the IPA, to purchase power from a repowered unit at the Meredosia energy center designed for permanent carbon dioxide capture and storage, annually over a 20-year period beginning in 2017, for its electric delivery service customers. The agreement is contingent on the parties interested in repowering the unit at the abandoned Meredosia energy center reaching certain milestones related to the construction and commencement of operations of this unit. Ameren will not repower the unit; 143 however, a sale of the unit to a third party is possible. Construction has not begun on the unit at this energy center; therefore, Ameren Illinois’ obligations are not certain at this time and consequently not included in the table above. If the plant is not in service by 2019, Ameren Illinois can terminate the agreement. Environmental Matters We are subject to various environmental laws and regulations enforced by federal, state, and local authorities. From the beginning phases of siting and development to the ongoing operation of existing or new electric generation, transmission and distribution facilities and natural gas storage, transmission and distribution facilities, our activities involve compliance with diverse environmental laws and regulations. These laws and regulations address emissions, discharges to water, water usage, impacts to air, land, and water, and chemical and waste handling. Complex and lengthy processes are required to obtain and renew approvals, permits, or 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. The EPA is developing environmental regulations that will have a significant impact on the electric utility industry. Over time, compliance with these regulations could be particularly costly for certain companies, including Ameren Missouri, that operate coal-fired energy centers. Significant new rules proposed or promulgated include the regulation of CO2 emissions from new energy centers; revised national ambient air quality standards for ozone, fine particulates, SO2, and NOx emissions; the CSAPR, which would have required further reductions of SO2 emissions and NOx emissions from energy centers; a regulation governing management of CCR and coal ash impoundments; the MATS, which require reduction of emissions of mercury, toxic metals, and acid gases from energy centers; revised NSPS for particulate matter, SO2, and NOx emissions from new sources; new effluent standards applicable to waste water discharges from energy centers and new regulations under the Clean Water Act that could require significant capital expenditures, such as modifications to water intake structures or new cooling towers at our energy centers. The EPA is expected to propose CO2 standards for existing fossil fuel-fired electric generation units in the future. These new and proposed regulations, if adopted, may be challenged through litigation, so their ultimate implementation, as well as the timing of any such implementation, is uncertain. Although many details of these future regulations are unknown, the combined effects of the new and proposed environmental regulations may result in significant capital expenditures and increased operating costs over the next five to ten years for Ameren and Ameren Missouri. Compliance with these environmental laws and regulations could be prohibitively expensive or could result in the closure or alteration of the operation of some of our energy centers. Ameren and Ameren Missouri would expect these costs to be recoverable through rates, but the nature and timing of costs, as well as the applicable regulatory framework, could result in regulatory lag. As of December 31, 2013, Ameren and Ameren Missouri estimate capital expenditure investments of $275 million to $350 million over the next five years to comply with existing environmental regulations. This estimate assumes that CCR will continue to be regulated as nonhazardous. This estimate does not include the impacts of regulations proposed by the EPA under the Clean Water Act, in March 2011, regarding cooling water intake structures or the impact of the effluent standards applicable to steam-electric generating units that the EPA proposed in April 2013, as the technology requirements of these final rules are not yet known. Considerable uncertainty remains in this estimate. The actual amount of capital expenditure investments to comply with existing environmental regulations may vary substantially from the above estimate due to uncertainty as to the precise compliance strategies that will be used and their ultimate cost, among other things. Ameren Missouri’s current environmental compliance plan for air emissions includes burning ultra-low-sulfur coal and installing new or optimizing existing pollution control equipment. Ameren Missouri has two scrubbers at its Sioux energy center, which are used to reduce SO2 emissions and other pollutants. Currently, Ameren Missouri’s compliance plan assumes the installation of additional controls including mercury control technology and precipitator upgrades at multiple energy centers within its coal-fired fleet during the next five years. However, Ameren Missouri is currently evaluating its operations and options to determine how to comply with the MATS and other recently finalized or proposed EPA regulations. Additional controls may be necessary, depending upon the resolution of the CSAPR litigation currently pending before the United States Supreme Court or if a new rule replacing CAIR is ultimately adopted, as discussed below. If CSAPR is implemented, Ameren Missouri may be required to install two additional scrubbers within the next ten years. Environmental compliance costs at some of Ameren Missouri’s energy centers could be prohibitive and additional capital investment or continued operations unwarranted. Ameren Missouri’s capital expenditures and other costs are subject to MoPSC prudence reviews, which could result in cost disallowances as well as regulatory lag. The following sections describe the more significant environmental laws and rules that affect or could affect our operations. Clean Air Act Both federal and state laws require significant reductions in SO2 and NOx emissions that result from burning fossil fuels. In 2005, the EPA issued regulations with respect to SO2 and NOx emissions (the CAIR). In December 2008, the United States Court of Appeals for the District of Columbia Circuit found various aspects of the law to be unlawful and remanded the CAIR to the EPA for 144 further action, but allowed the CAIR’s cap-and-trade programs to remain effective until they are replaced by the EPA. In July 2011, the EPA issued the CSAPR as the CAIR replacement. The CSAPR regulations were vacated by the United States Court of Appeals for the District of Columbia Circuit. The EPA appealed to the United States Supreme Court, and a ruling is expected by June 2014. The EPA will continue to administer the CAIR until a new rule is ultimately adopted or until the United States Supreme Court overturns the decision to vacate the CSAPR. In December 2011, the EPA issued the MATS under the Clean Air Act, which require emission reductions for mercury and other hazardous air pollutants, such as acid gases, toxic metals, and hydrogen chloride emissions. The MATS do not require a specific control technology to achieve the emission reductions. The MATS will apply to each unit at a coal-fired power plant; however in certain cases, emission compliance can be achieved by averaging emissions from similar electric generating units at the same power plant. Compliance is required by April 2015 or, with a case-by-case extension, by April 2016. Ameren Missouri’s Labadie and Meramec energy centers requested and were granted extensions to April 2016 to comply with the MATS. Emission Allowances The Clean Air Act created marketable commodities called emission allowances under the acid rain program, the NOx budget trading program, and the CAIR. Ameren Missouri expects to have enough CAIR allowances for 2014 to avoid making external purchases to comply with these programs. Greenhouse Gas Regulation In December 2009, the EPA issued its “endangerment finding” under the Clean Air Act, which stated that greenhouse gas emissions, including CO2, endanger human health and welfare and that emissions of greenhouse gases from motor vehicles contribute to that endangerment. In March 2010, the EPA issued a determination that greenhouse gas emissions from stationary sources, such as power plants, would be subject to regulation under the Clean Air Act effective the beginning of 2011. As a result of these actions, we are required to consider the emissions of greenhouse gases in any air permit application. Recognizing the difficulties presented by regulating at once virtually all emitters of greenhouse gases, the EPA issued the “Tailoring Rule,” which established new higher emission thresholds beginning in January 2011 for regulating greenhouse gas emissions from stationary sources, such as power plants. The rule requires any source that already has an operating permit to have greenhouse- gas-specific provisions added to its permits upon renewal. Currently, all Ameren energy centers have operating permits that have been modified to address greenhouse gas emissions. The Tailoring Rule also provides that if projects performed at major sources or new major sources result in an increase in emissions of greenhouse gases over an applicable annual threshold, such projects could trigger permitting requirements under the NSR programs and the application of best available control technology to control greenhouse gas emissions. In June 2012, the United States Court of Appeals for the District of Columbia Circuit upheld the Tailoring Rule. Industry groups and a coalition of states filed petitions in April 2013 requesting that the United States Supreme Court review the circuit court’s decision. In October 2013, the United States Supreme Court granted limited review of one petition, agreeing to consider whether the Clean Air Act authorizes the EPA to regulate emissions of greenhouse gases from stationary sources, including power plants, as a result of its determination to regulate greenhouse gas emissions from motor vehicles. A ruling is expected in 2014. In June 2013, the Obama administration announced that it had directed the EPA to set CO2 emissions standards for both new and existing power plants. The EPA published proposed regulations in January 2014 that would set revised CO2 emissions standards for new electricity generating units. The proposed standards would establish separate emissions limits for new natural gas-fired plants and new coal-fired plants. In addition, the Obama administration directed the EPA to propose a CO2 emissions standard for existing power plants by June 2014 and to finalize such standard by June 2015. Currently, the Ameren Companies are unable to predict the outcome or impacts of such future regulations. Future federal and state legislation or regulations that mandate limits on the emission of greenhouse gases may result in significant increases in capital expenditures and operating costs, which, in turn, could lead to increased liquidity needs and higher financing costs. These compliance costs could be prohibitive at some of our energy centers, as the expected return from these investments, at current market prices for energy and capacity, might not justify the required capital expenditures or their continued operation, which could result in the impairment of long-lived assets if costs are not recovered through rates. To the extent that Ameren Missouri requests recovery of these costs through rates, its regulators might delay or deny timely recovery. Mandatory limits on the emission of greenhouse gases could increase costs for our customers or have a material adverse impact on Ameren’s and Ameren Missouri’s results of operations, financial position, and liquidity. To the extent investments in environmental control technology are reflected and recovered on a timely basis in rate base, Ameren’s and Ameren Missouri’s earnings may benefit from increased investment in such control technology. NSR and Clean Air Litigation In January 2011, the 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. The EPA’s complaint, as amended in October 2013, alleges that in performing projects at its Rush Island 145 coal-fired energy center in 2007 and 2010, Ameren Missouri violated provisions of the Clean Air Act and Missouri law. In January 2012, the United States District Court granted, in part, Ameren Missouri’s motion to dismiss various aspects of the EPA’s penalty claims. The EPA’s claims for unspecified injunctive relief remain. The trial in this matter is currently scheduled to begin in January 2015. Ameren Missouri believes its defenses are meritorious and will defend itself vigorously. However, there can be no assurances that it will be successful in its efforts. Ultimate resolution of these matters could have a material adverse impact on the future results of operations, financial position, and liquidity of Ameren and Ameren Missouri. A resolution could result in increased capital expenditures for the installation of pollution control equipment, increased operations and maintenance expenses, and penalties. We are unable to predict the ultimate resolution of these matters or the costs that might be incurred. Clean Water Act In March 2011, the EPA announced a proposed rule applicable to cooling water intake structures at existing power plants. The proposed rule would impose standards for reducing the mortality of aquatic organisms impinged on the plant’s intake screens or entrained through the plant’s cooling water system. All coal-fired, nuclear, and combined cycle energy centers at Ameren Missouri with cooling water systems are subject to this proposed rule. The EPA has agreed to finalize the rule in April 2014. When finalized the final rule could have an adverse effect on our results of operations, financial position, and liquidity if its implementation requires the installation of cooling towers or extensive modifications to the cooling water systems at our energy centers. In April 2013, the EPA announced its proposal to revise the effluent limitation guidelines applicable to steam electric generating units under the Clean Water Act. Effluent limitation guidelines are national standards for wastewater discharges to surface water that are based on the effectiveness of available control technology. The EPA’s proposed rule raised several compliance options that would prohibit effluent discharges of certain, but not all, waste streams and impose more stringent limitations on certain components in wastewater discharges from power plants. If the rule is enacted as proposed, Ameren Missouri would be subject to the revised limitations beginning as early as July 1, 2017, but no later than July 1, 2022. Ameren is reviewing the proposed rule and evaluating its potential impact on operations. The EPA expects to issue final guidelines in April 2014. Ash Management In May 2010, the EPA announced proposed new regulations regarding the management and disposal of CCR, which could affect future disposal and handling costs at our energy centers. Those proposed regulations include two options for managing CCRs, under either solid or hazardous waste regulations, but either alternative would allow for some continued beneficial uses, such as recycling of CCR without classifying it as waste. The EPA announced that its April 2013 proposed revisions to the effluent limitations applicable to steam electric generating units would apply to ash ponds and CCR management and that it intended to align this proposal with the CCR rules when finalized. The EPA is expected to issue a final rule in December 2014. Ameren Missouri is currently evaluating all of the proposed regulations to determine whether current management of CCR, including beneficial reuse, and the use of the ash ponds should be altered. Ameren Missouri is evaluating the potential costs associated with compliance with the proposed regulation of CCR impoundments and landfills, which could be material, if such regulations are adopted. Remediation We are involved in a number of remediation actions to clean up sites impacted by hazardous substances as required by federal and state law. Such statutes require that responsible parties fund remediation actions regardless of their degree of fault, the legality of original disposal, or the ownership of a disposal site. Ameren Missouri and Ameren Illinois have each been identified by the federal or state governments as a potentially responsible party (PRP) at several contaminated sites. As of December 31, 2013, Ameren Illinois owned or was otherwise responsible for 44 former MGP sites in Illinois. These sites are in various stages of investigation, evaluation, remediation, and closure. Based on current estimated plans, Ameren Illinois could substantially conclude remediation efforts at most of these sites by 2018. The ICC permits Ameren Illinois to recover remediation and litigation costs associated with its former MGP sites from its electric and natural gas utility customers through environmental adjustment rate riders. To be recoverable, such costs must be prudently incurred. Costs are subject to annual review by the ICC. As of December 31, 2013, Ameren Missouri has one remaining former MGP site for which remediation is scheduled. Remediation is complete at the other Ameren Missouri former MGP sites. Ameren Missouri does not currently have a rate rider mechanism that permits it to recover from utility customers remediation costs associated with MGP sites. The following table presents, as of December 31, 2013, the estimated obligation to complete the remediation of these former MGP sites. Estimate Low High Recorded Liability(a) Ameren . . . . . . . . . . . . . . . . . . . . Ameren Missouri . . . . . . . . . . . . . Ameren Illinois . . . . . . . . . . . . . . . $ 278 4 274 $ 338 5 333 $ 278 4 274 (a) Recorded liability represents the estimated minimum probable obligations, as no other amount within the range provided a better estimate. 146 The scope and extent to which these former MGP sites are remediated may increase as remediation efforts continue. Considerable uncertainty remains in these estimates, as many factors can influence the ultimate actual costs, including site specific unanticipated underground structures, the degree to which groundwater is encountered, regulatory changes, local ordinances and site accessibility. The actual costs may vary substantially from these estimates. Ameren Illinois used an off-site landfill, which Ameren Illinois did not own, in connection with the former operation of an energy center. Ameren Illinois could be required to perform certain maintenance activities associated with that landfill. As of December 31, 2013, Ameren Illinois estimated the obligation related to this site at $0.5 million to $6 million. Ameren Illinois recorded a liability of $0.5 million to represent its estimated minimum obligation for this site, as no other amount within the range was a better estimate. Ameren Illinois is also responsible for the cleanup of some underground storage tanks and a water treatment plant in Illinois. As of December 31, 2013, Ameren Illinois recorded a liability of $0.8 million to represent its estimate of the obligation for these sites. Ameren Missouri is investigating and addressing two waste sites in Missouri as a result of federal agency mandates. One of the cleanup sites is a former coal tar distillery located in St. Louis, Missouri. In 2008, the EPA issued an administrative order to Ameren Missouri pertaining to this distillery operated by Koppers Company or its predecessor and successor companies. While Ameren Missouri is the current owner of the site, it did not conduct any of the manufacturing operations involving coal tar or its byproducts. Ameren Missouri, along with two other PRPs, is currently performing a site investigation. As of December 31, 2013, Ameren Missouri estimated its obligation at $2 million to $5 million. Ameren Missouri recorded a liability of $2 million to represent its estimated minimum obligation, as no other amount within the range was a better estimate. Ameren Missouri’s other active federal agency-mandated cleanup site in Missouri is in Cape Girardeau. Ameren Missouri was a customer of an electrical equipment repair and disposal company that previously operated a facility at this site. A trust was established in the early 1990s by several businesses and governmental agencies to fund the investigation and cleanup of this site, which was completed in 2005. Ameren Missouri anticipates that this trust fund will be sufficient to complete the remaining adjacent off-site cleanup, and therefore, Ameren Missouri believes it has no liability at December 31, 2013, for this site. Ameren Missouri also has a federal agency mandate to complete an investigation for a site in Illinois. In 2000, the EPA notified Ameren Missouri and numerous other companies, including Solutia, that former landfills and lagoons in Sauget, Illinois, may contain soil and groundwater contamination. These sites are known as Sauget Area 2. From about 1926 until 1976, Ameren Missouri operated an energy center adjacent to Sauget Area 2. Ameren Missouri currently owns a parcel of property that was once used as a landfill. Under the terms of an Administrative Order on Consent, Ameren Missouri joined with other potentially responsible parties to evaluate the extent of potential contamination with respect to Sauget Area 2. The Sauget Area 2 investigations overseen by the EPA have been completed. In December 2013, the EPA issued its record of decision approving the investigation and the remediation alternatives recommended by the potentially responsible parties. Further negotiation among the potentially responsible parties will determine how to fund the implementation of the EPA approved cleanup remedies. As of December 31, 2013, Ameren Missouri estimated its obligation related to Sauget Area 2 at $0.3 million to $10 million. Ameren Missouri recorded a liability of $0.3 million to represent its estimated minimum obligation, as no other amount within the range was a better estimate. In December 2012, Ameren Missouri signed an administrative order with the EPA and agreed to investigate soil and groundwater conditions at an Ameren Missouri owned substation in St. Charles, Missouri. As of December 31, 2013, Ameren Missouri estimated the obligation related to the cleanup at $1.6 million to $4.5 million. Ameren Missouri recorded a liability of $1.6 million to represent its estimated minimum obligation for this site, as no other amount within the range was a better estimate. 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 practices will result in future environmental commitments or will affect our results of operations, financial position, or liquidity. Pumped-storage Hydroelectric Facility Breach In December 2005, there was a breach of the upper reservoir at Ameren Missouri’s Taum Sauk pumped-storage hydroelectric energy center. This resulted in significant flooding in the local area, which damaged a state park. The rebuilt Taum Sauk energy center became fully operational in April 2010. Ameren Missouri had liability insurance coverage for the Taum Sauk incident, subject to certain limits and deductibles. As of December 31, 2013, Ameren Missouri had an insurance receivable balance of $68 million. In June 2010, Ameren Missouri sued an insurance company that was providing Ameren Missouri with liability coverage on the date of the Taum Sauk incident. In the litigation, filed in the United States District Court for the Eastern District of Missouri, Ameren Missouri claimed that the insurance company breached its duty to indemnify Ameren Missouri for the losses resulting from the incident. In January 2011, the district court ruled that the parties must first pursue alternative dispute resolution and enforced the forum selection clause of their coverage 147 agreement. The forum selection clause requires use of New York law and effectively requires mandatory arbitration. Ameren Missouri appealed the January 2011 ruling to the United States Court of Appeals for the Eighth Circuit. In August 2012, the court of appeals remanded the case to the district court for consideration of whether Missouri public policy voids the forum selection clause. In September 2013, the district court ruled that Missouri public policy does void the forum selection clause. Separately, in April 2012, Ameren Missouri sued a second insurance company that was providing Ameren Missouri with liability coverage on the date of the Taum Sauk incident. In the April 2012 litigation, which is pending in the United States District Court for the Eastern District of Missouri, Ameren Missouri claimed the insurance company breached its duty to indemnify Ameren Missouri for the losses resulting from the incident. The insurance company filed a motion to compel arbitration, which the district court denied. In April 2013, the United States Court of Appeals for the Eighth Circuit affirmed the district court’s denial of the insurer’s motion and remanded the case to the district court. Ameren’s and Ameren Missouri’s results of operations, financial position and liquidity could be adversely affected if Ameren Missouri’s remaining liability insurance claims are not paid by insurers. Asbestos-related Litigation Ameren, Ameren Missouri and Ameren Illinois have been named, along with numerous other parties, in a number of lawsuits filed by plaintiffs claiming varying degrees of injury from asbestos exposure at our present or former energy centers. Most have been filed in the Circuit Court of Madison County, Illinois. The total number of defendants named in each case varies, with the average number of parties being 82 as of December 31, 2013. Each lawsuit seeks unspecified damages that, if awarded at trial, typically would be shared among the various defendants. In connection with the divestiture of New AER to IPH, certain agreements related to former Ameren Illinois energy centers were amended to provide that Ameren Illinois will continue to retain asbestos exposure-related liabilities for claims arising or existing from activities prior to its transfer of the ownership of the former Ameren Illinois energy centers to New AER. IPH will be responsible for any asbestos-related claims arising from activities that occur after the effective date of the divestiture. No claims arose solely from activities in the period after the transfer of the energy centers from Ameren Illinois to AER, but before IPH took ownership of New AER. The following table presents the pending asbestos- related lawsuits filed against the Ameren Companies as of December 31, 2013: Ameren 1 Ameren Missouri 47 Ameren Illinois 50 Total(a) 71 148 (a) Total does not equal the sum of the subsidiary unit lawsuits because some of the lawsuits name multiple Ameren entities as defendants. At December 31, 2013, Ameren, Ameren Missouri and Ameren Illinois had liabilities of $11 million, $5 million, and $6 million, respectively, recorded to represent their best estimate of their obligations related to asbestos claims. Ameren Illinois has a tariff rider to recover the costs of IP asbestos-related litigation claims, subject to the following terms: 90% of cash expenditures in excess of the amount included in base electric rates are to be recovered from a trust fund that was established when Ameren acquired IP. At December 31, 2013, the trust fund balance was $23 million, including accumulated interest. If cash expenditures are less than the amount in base rates, Ameren Illinois will contribute 90% of the difference to the trust fund. Once the trust fund is depleted, 90% of allowed cash expenditures in excess of base rates will be recovered through charges assessed to customers under the tariff rider. The rider will permit recovery from customers within IP’s historical service territory. Ameren Illinois Municipal Taxes Ameren Illinois received tax liability notices from the city of O’Fallon, Illinois, relating to prior-period electric and natural gas municipal taxes. The city alleges that Ameren Illinois failed to collect prior-period taxes from more than 2,400 accounts, primarily in annexed areas, for the period 2004 through 2012. In July 2013, the O’Fallon city administrator issued an order stating that Ameren Illinois was liable to the city of O’Fallon for $4 million. In August 2013, Ameren Illinois filed an appeal and a stay of the O’Fallon city administrator’s order to the St. Clair County Circuit Court. In addition, in December 2012, the city of Peoria issued a tax liability notice alleging that Ameren Illinois failed to collect prior-period municipal taxes from certain accounts. In September 2013, a hearing officer issued an order stating that Ameren Illinois was liable to the city of Peoria for $0.5 million. Ameren Illinois filed an appeal and a stay of the order to the Peoria County Circuit Court. Ameren Illinois believes its defenses to the allegations are meritorious and will defend itself vigorously. As of December 31, 2013, Ameren Illinois estimated its obligation at $1 million to $5 million. Ameren Illinois recorded a liability of $1 million to represent its estimated minimum obligation to the city of O’Fallon and the city of Peoria, as no other amount within the range was a better estimate. In addition, at the end of 2012, five other cities issued tax liability notices alleging that Ameren Illinois failed to collect prior-period taxes from certain accounts. At this time, it is premature in Ameren Illinois’ review of the additional notices received at the end of 2012 to reasonably estimate any likelihood of loss. NOTE 16 – DIVESTITURE TRANSACTIONS AND DISCONTINUED OPERATIONS Transaction Agreement with IPH On December 2, 2013, Ameren completed the divestiture of New AER to IPH, in accordance with the transaction agreement between Ameren and IPH dated March 14, 2013, as amended by a letter agreement entered into by Ameren and IPH on December 2, 2013. IPH acquired all of the outstanding limited liability interests in New AER, which was a newly created, wholly owned subsidiary of AER. Prior to the closing, AER effected a reorganization that, among other things, transferred substantially all of its assets and liabilities to New AER, other than (i) any outstanding debt obligations of AER to Ameren or its other subsidiaries, except for certain intercompany balances discussed below; (ii) the assets and liabilities associated with Genco’s Meredosia and Hutsonville energy centers; (iii) the obligations relating to Ameren’s single-employer pension and postretirement benefit plans; and (iv) the deferred income tax assets and liabilities associated with Ameren’s ownership of these retained assets and liabilities. Ameren retained certain pension and postretirement benefit obligations associated with current and former employees of AER, with the exception of the pension and postretirement benefit obligations associated with current and former employees of EEI, which were assumed by IPH. Ameren retained the Meredosia and Hutsonville energy centers, including their AROs, which totaled $31 million as of December 31, 2013. These energy centers were abandoned and had an immaterial property and plant asset balance as of December 31, 2013. All other AROs associated with AER were assumed by New AER or by Rockland Capital, the third-party buyer of the Grand Tower energy center, as discussed below. Upon the IPH transaction agreement closing, all intercompany agreements and debt that existed between New AER and its subsidiaries, on the one hand, and Ameren and its non-New AER affiliates, on the other hand, with the exception of certain agreements, such as supply obligations to Ameren Illinois, a note from Marketing Company to Ameren relating to cash collateral that remained outstanding at closing, Genco money pool advances and certain New AER subsidiary money pool borrowings, were either retained or cancelled by Ameren, without any cost or obligation to IPH or New AER and its subsidiaries. Immediately prior to the closing of the divestiture, the money pool borrowings through which Ameren provided cash collateral to Marketing Company were converted to a note payable to Ameren, which is payable, with interest, 24 months after closing or sooner as cash collateral requirements are reduced. The balance of the note was $18 million at December 31, 2013, and is reflected on Ameren’s consolidated balance sheet in “Other assets.” Pursuant to the transaction agreement, as amended by the December 2, 2013, letter agreement, Ameren caused $235 million of cash to be retained at New AER immediately prior to closing, which included amounts previously paid to Genco for the sale of the Elgin, Gibson City, and Grand Tower energy centers to Medina Valley as well as additional amounts retained at Genco, AERG, and Marketing Company. Within 120 days after the closing of the divestiture, a working capital adjustment will be finalized, which may result in a cash payment from Ameren to IPH or from IPH to Ameren. Ameren received no cash proceeds as a result of the divestiture of New AER. Pursuant to the transaction agreement, as amended, Ameren is obligated to pay up to $39 million for certain contingent liabilities. Of these liabilities, $29 million are included in “Other deferred credits and liabilities” and $10 million are included in “Accounts and wages payable” on Ameren’s December 31, 2013 consolidated balance sheet. As a condition to the transaction agreement, Genco exercised the amended put option agreement for the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Medina Valley. In October 2013, Genco completed the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Medina Valley, receiving total payments of $137.5 million. The third-party sale of these energy centers to Rockland Capital was completed on January 31, 2014 and is discussed below. Sale of Gas-fired Energy Centers Prior to entry into the transaction agreement with IPH, Genco entered into a put option agreement, as amended, with Medina Valley. This agreement gave Genco the option to sell to Medina Valley the Elgin, Gibson City, and Grand Tower gas-fired energy centers for the fair market value of the energy centers, as determined by three independent appraisers. Genco exercised its option, and in October 2013 completed its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Medina Valley for $137.5 million, which was the fair value of the gas-fired energy centers as determined by the three independent appraisers. The transaction agreement with IPH, as amended, provides that if the Elgin, Gibson City, and Grand Tower gas-fired energy centers are subsequently sold by Medina Valley and if Medina Valley receives additional proceeds from such sale, Medina Valley will pay Genco any proceeds from such sale, net of taxes and other expenses, in excess of the $137.5 million previously paid to Genco. On January 31, 2014, Medina Valley completed the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital for a total purchase price of $168 million, before consideration of a net working capital adjustment. The agreement with Rockland Capital required $17 million of the purchase price to be held in escrow until the two-year anniversary of the closing of the sale to fund certain indemnity obligations, if any, of Medina Valley. The net working capital adjustment will be finalized within 120 days after the January 31, 2014, closing date. As a result, pending final resolution of the net working capital adjustment, taxes, and other expenses, Medina Valley expects to pay Genco any remaining portion of the escrow 149 balance on January 31, 2016. Ameren will not record a gain from its sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers. Discontinued Operations Presentation As of March 14, 2013, Ameren determined that New AER and the Elgin, Gibson City, and Grand Tower gas-fired energy centers qualified for discontinued operations presentation. In addition, effective December 2, 2013, coinciding with the completion of the divestiture of New AER to IPH, Ameren determined that the Meredosia and Hutsonville energy centers had been abandoned. Ameren is prohibited from operating these energy centers through December 31, 2020, as a provision of the Illinois Pollution Control Board’s November 2013 order granting IPH a variance of the MPS. As a result, Ameren determined the Meredosia and Hutsonville energy centers qualified for discontinued operations presentation as of December 2, 2013. New AER and the Elgin, Gibson City, Grand Tower, Meredosia, and Hutsonville energy centers have been classified collectively in Ameren’s consolidated financial statements as discontinued operations for all periods presented in this report. The disposal groups have been aggregated in the disclosures below. The following table presents the components of discontinued operations in Ameren’s consolidated statement of income (loss) for the years ended December 31, 2013, 2012 and 2011: Year ended 2013 2012 2011 Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,037 $ 1,047 (1,207)(a) (3,474)(b) $ 1,358 (1,150) Operating income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income (loss) before income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income tax (expense) benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (170) (1) (39) (210) (13) (2,427) - (56) (2,483) 987 208 1 (64) 145 (56) Income (loss) from discontinued operations, net of taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (223) $ (1,496) $ 89 (a) (b) Includes a $201 million pretax loss on disposal relating to the New AER divestiture. Includes a noncash pretax asset impairment charge of $628 million to reduce the carrying value of AERG’s Duck Creek energy center to its estimated fair value under held and used accounting guidance. In addition, includes a noncash pretax asset impairment charge of $1.95 billion to reduce the carrying values of all the AER coal and natural gas-fired energy centers, except the Joppa coal-fired energy center, to their estimated fair values, under held and used accounting guidance, as a result of the decision in December 2012 that Ameren intended to exit the Merchant Generation business. Upon completion of the divestiture of New AER, Ameren finalized its loss on disposal. Ameren received no cash proceeds from IPH for the divestiture of New AER. Ameren recorded a pretax charge to earnings related to the New AER divestiture of $201 million for the year ended December 31, 2013. The loss was recorded in “Operating expenses” within the components of the discontinued operations statement of income (loss). The ultimate loss on disposal may differ as a result of the finalization of the working capital adjustment within 120 days of close. In 2013, Ameren adjusted the accumulated deferred income taxes on its consolidated balance sheet to reflect the excess of tax basis over financial reporting basis of its stock investment in AER. This change in basis resulted in a discontinued operations deferred tax expense of $99 million, which was partially offset by the expected tax benefits of $86 million related to the pretax loss from discontinued operations including the loss on disposal, during the year ended December 31, 2013. The final tax basis of the AER disposal group and the related tax benefit resulting from the transaction agreement with IPH are dependent upon the resolution of tax matters under IRS audit, including the adoption of recently issued guidance from the IRS related to tangible property repairs and other matters. As a result, tax expense and benefits ultimately realized in discontinued operations may differ materially from those recorded as of December 31, 2013. As the Elgin, Gibson City, and Grand Tower gas-fired energy center disposal group continued to meet the discontinued operations criteria at December 31, 2013, Ameren evaluated whether any impairment existed by comparing the disposal group’s carrying value to the estimated fair value of the disposal group, less cost to sell. In December 2012, Ameren recorded a noncash long-lived asset impairment charge to reduce the carrying value of AER’s energy centers, including the Elgin, Gibson City, and Grand Tower gas-fired energy centers, to their estimated fair values under the accounting guidance for held and used assets. Ameren did not record any additional impairment relating to the Elgin, Gibson City, and Grand Tower energy centers for the year ended December 31, 2013. As discussed above, on January 31, 2014, Medina Valley completed the sale of the Elgin, Gibson City, and Grand Tower gas-fired energy centers to Rockland Capital for a total purchase price of $168 million, before consideration of a net working capital adjustment. Ameren will not recognize a gain from the third party sale to Rockland Capital for any value in excess of its $137.5 million carrying value for this 150 disposal group since any excess amount that Medina Valley may receive, net of taxes and other expenses, over the carrying value, will ultimately be paid to Genco pursuant to the transaction agreement with IPH. Long-lived Asset Impairments New AER and the Elgin, Gibson City, and Grand Tower energy centers were impaired under held and used accounting guidance in 2012 and the Meredosia and Hutsonville energy centers were impaired under held and used accounting guidance in 2011. The 2012 and 2011 impairments are discussed below. As a result of the December 2012 decision that Ameren intended to, and it was probable that it would, exit the Merchant Generation segment before the end of the Merchant Generation long-lived assets’ previously estimated useful lives, Ameren determined that estimated undiscounted cash flows during the period in which it expected to continue to own certain energy centers would be insufficient to recover the carrying value of those energy centers. Accordingly, Ameren recorded a noncash pretax impairment charge of $1.95 billion in the fourth quarter of 2012 to reduce the carrying values of all of the Merchant Generation’s coal and natural gas-fired energy centers, except the Joppa coal-fired energy center, to their estimated fair values. The estimated undiscounted cash flows of the Joppa coal-fired energy center exceeded its carrying value; therefore, the Joppa coal-fired energy center was unimpaired. In early 2012, the observable market price for power for delivery in that year and in future years in the Midwest sharply declined below 2011 levels, primarily because of declining natural gas prices and the impact of the stay of the CSAPR. As a result of this sharp decline in the market price of power and the related impact on electric margins, Genco decelerated the construction of two scrubbers at its Newton energy center in February 2012. The sharp decline in the market price of power in early 2012 and the related impact on electric margins, as well as the deceleration of construction of Genco’s Newton energy center scrubber project, caused Ameren to evaluate, during the first quarter of 2012, whether the carrying values of Merchant Generation coal-fired energy centers were recoverable. AERG’s Duck Creek energy center’s carrying value exceeded its estimated undiscounted future cash flows. As a result, Ameren recorded a noncash pretax asset impairment charge of $628 million to reduce the carrying value of that energy center to its estimated fair value during the first quarter of 2012. In December 2011, Genco ceased operations at its Meredosia and Hutsonville energy centers. As a result, Ameren recorded a noncash pretax asset impairment charge of $26 million to reduce the carrying value of the Meredosia and Hutsonville energy centers to their estimated fair values and a $4 million impairment for materials and supplies. Key assumptions used in the determination of estimated undiscounted cash flows for the 2012 and 2011 long-lived assets tested for impairment under held and used accounting guidance discussed above included forward price projections for energy and fuel costs, the expected life or duration of ownership of the long-lived assets, environmental compliance costs and strategies, and operating costs. Those same cash flow assumptions, along with a discount rate and terminal year earnings multiples, were used to estimate the fair value of each energy center. These assumptions are subject to a high degree of judgment and complexity. The fair value estimate of these long-lived assets was based on a combination of the income approach, which considers discounted cash flows, and the market approach, which considers market multiples for similar assets within the electric generation industry. The fair value estimate was determined using observable inputs and significant unobservable inputs, which are Level 3 inputs as defined by accounting guidance for fair value measurements. 151 The following table presents the carrying amounts of the components of assets and liabilities segregated on Ameren’s consolidated balance sheets as discontinued operations at December 31, 2013, and 2012: December 31, 2013 December 31, 2012 Assets of discontinued operations Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts receivable and unbilled revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Materials and supplies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mark-to-market derivative assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Property and plant, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated deferred income taxes, net(a) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets of discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities of discontinued operations Accounts payable and other current obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mark-to-market derivative liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Asset retirement obligations(b) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and other postretirement benefits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total liabilities of discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated other comprehensive income(c) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncontrolling interest(d) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ $ $ $ - 5 5 - 142 13 - 165 5 - - 40 - - 45 - - $ $ $ $ $ $ 25 102 135 102 748 395 104 1,611 141 63 824 97 40 28 1,193 19 8 (a) The December 31, 2013 balance primarily consists of deferred income tax assets related to the abandoned Meredosia and Hutsonville energy (b) centers. Includes AROs associated with the abandoned Meredosia and Hutsonville energy centers of $31 million and $26 million at December 31, 2013, and 2012, respectively. (c) Accumulated other comprehensive income related to discontinued operations included in “Accumulated other comprehensive loss” on Ameren’s December 31, 2012, consolidated balance sheet. This balance related to New AER assets and liabilities that were realized or removed from Ameren’s consolidated balance sheet either before or at the December 2, 2013 closing of the New AER divestiture. (d) The 20% ownership interest of EEI not owned by Ameren was included in “Noncontrolling interests” on Ameren’s December 31, 2012, consolidated balance sheet. This noncontrolling interest was removed from Ameren’s consolidated balance sheet at the December 2, 2013 closing of the New AER divestiture. Ameren has continuing transactions with New AER. Ameren Illinois has power supply agreements with Marketing Company, which are a result of the power procurement process in Illinois administered by the IPA, as required by the Illinois Public Utilities Act. Ameren Illinois continues to purchase power and to purchase trade receivables as required by Illinois law. Ameren Illinois and ATXI continue to sell transmission services to Marketing Company. Also, the transaction agreement requires Ameren (parent) to maintain certain guarantees discussed below. Immediately prior to the transaction agreement closing, the money pool borrowings through which Ameren provided cash collateral to Marketing Company were converted to a note payable to Ameren, which is payable, with interest, 24 months after closing or sooner as cash collateral requirements are reduced. Also, within 120 days after closing, a working capital adjustment will be finalized, which may result in a cash payment from Ameren to New AER or from New AER to Ameren. Ameren has determined that the continuing cash flows generated by these arrangements are not significant and, accordingly, are not deemed to be direct cash flows of the divested business. Additionally, these arrangements do not provide Ameren with the ability to significantly influence the operating results of New AER. Ameren will not have significant continuing involvement with or material cash flows from the Elgin, Gibson City, or Grand Tower energy centers after their sale. Ameren Guarantees Upon the divestiture of New AER, the transaction agreement between Ameren and IPH requires Ameren (parent) to maintain its financial obligations with respect to all credit support provided to New AER as of the closing date of such divestiture. Ameren must also provide such additional credit support as required by contracts entered into prior to the closing date, in each case for up to 24 months after the closing. IPH shall indemnify Ameren for any payments Ameren makes pursuant to these credit support obligations if the counterparty does not return the posted collateral to Ameren. IPH’s indemnification obligation is secured by certain AERG and Genco assets. In addition, Dynegy has provided a limited guarantee of $25 million to Ameren (parent) pursuant to which Dynegy will, among other things, guarantee IPH’s indemnification obligations for a period of up to 24 months after the closing. 152 At December 31, 2013, Ameren had a total of $190 million in guarantees outstanding, which included: ‰ ‰ $176 million related to guarantees supporting Marketing Company for physically and financially settled power transactions with its counterparties that were in place at the December 2, 2013 closing of the divestiture, as well as for Marketing Company’s clearing broker and other service agreements. If Marketing Company did not fulfill its obligations to these counterparties who had active open positions as of December 31, 2013, Ameren would have been required under its guarantees to provide $6 million to the counterparties. $14 million related to requirements for leasing agreements and potential environmental obligations. Additionally, at December 31, 2013, Ameren had issued letters of credit totaling $11 million as credit support on behalf of New AER. Ameren has not recorded a reserve for these contingent obligations because it does not believe a payment for any of these guarantees is probable as of December 31, 2013. NOTE 17 – SEGMENT INFORMATION Ameren has two reportable segments: Ameren Missouri and Ameren Illinois. The Ameren Missouri segment for both Ameren and Ameren Missouri includes all the operations of Ameren Missouri’s business as described in Note 1 – Summary of Significant Accounting Policies. The Ameren Illinois segment for both Ameren and Ameren Illinois consists of all of the operations of Ameren Illinois as described in Note 1 – Summary of Significant Accounting Policies. The category called Other primarily includes Ameren parent company activities, Ameren Services, and ATXI. The Other category also includes certain corporate activities previously included in the Merchant Generation segment. See Note 16 – Divestiture Transactions and Discontinued Operations for additional information. The following table presents information about the reported revenues and specified items reflected in Ameren’s net income attributable to Ameren Corporation from continuing operations for the years ended December 31, 2013, 2012, and 2011, and total assets in continuing operations as of December 31, 2013, 2012, and 2011. Ameren Ameren Missouri Ameren Illinois Other Intersegment Eliminations Consolidated 2013 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 External revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net income (loss) attributable to Ameren Corporation from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ $ 3,516 25 454 27 210 242 395 648 12,904 3,252 20 440 32 223 252 416 595 13,043 3,360 23 408 30 209 161 287 550 12,757 $ $ $ 2,307 4 243 2 143 110 160 701 7,454 2,524 1 221 - 129 94 141 442 7,282 2,784 3 215 1 136 127 193 351 7,213 $ $ $ 15 2 9 1 45 (41) (43) 30(a) 752 5 3 12 - 40 (39) (41) 26(a) 1,228 4 3 20 - 42 (34) $ $ $ - (31) - - - - - - (233) - (24) - - - - - - (934) - (29) - - - - $ $ $ 5,838 - 706 30 398 311 512 1,379 20,877(b) 5,781 - 673 32 392 307 516 1,063 20,619(b) 6,148 - 643 31 387 254 (49) (20)(a) 1,211 - - (1,179) 431 881 20,002(b) . Includes the elimination of intercompany transfers. (a) (b) Excludes total assets from discontinued operations of $165 million, $1,611 million, and $3,721 million as of December 31, 2013, 2012, and 2011, respectively. 153 SELECTED QUARTERLY INFORMATION (Unaudited) (In millions, except per share amounts) Ameren Quarter ended(a) 2013 2012 March 31 June 30 September 30 December 31 March 31 June 30 September 30 December 31 Operating revenues . . . . . . . . . . . . . . . . . . . . . $ 1,475 $ 1,403 261 Operating income . . . . . . . . . . . . . . . . . . . . . . . 96 Net income (loss)(b) . . . . . . . . . . . . . . . . . . . . . 185 (143) $ 1,638 567 304 $ 1,322 171 38 $ 1,412 $ 1,402 347 210 159 (403) $ 1,709 570 374 $ 1,258 112 (1,155) Net income attributable to Ameren Corporation – continuing operations . . . . . . $ 54 $ 105 $ 305 $ 48 $ 38 $ 164 $ 302 $ 12 Net income (loss) attributable to Ameren Corporation – discontinued operations(b) . . . (199) (10) (3) (11) (441) 47 72 (1,168) Net income (loss) attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . $ (145) $ 95 Earnings per common share – basic – continuing operations . . . . . . . . . . . . . . . . . $ 0.22 $ 0.44 Earnings (loss) per common share – basic – discontinued operations . . . . . . . . . . . . . . . . (0.82) (0.05) Earnings (loss) per common share – basic . . . $ (0.60) $ 0.39 Earnings per common share – diluted – continuing operations . . . . . . . . . . . . . . . . . $ 0.22 $ 0.44 $ $ $ $ 302 1.26 (0.01) 1.25 1.25 $ $ $ $ 37 $ (403) $ 211 0.19 $ 0.16 $ 0.67 (0.04) (1.82) 0.20 0.15 $ (1.66) $ 0.87 0.19 $ 0.16 $ 0.67 Earnings (loss) per common share – diluted – discontinued operations . . . . . . . . . . . . . . . . Earnings (loss) per common share – (0.82) (0.05) (0.01) (0.04) (1.82) 0.20 $ $ $ $ 374 $ (1,156) 1.25 $ 0.05 0.29 1.54 1.25 0.29 $ $ (4.81) (4.76) 0.05 (4.81) diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (0.60) $ 0.39 $ 1.24 $ 0.15 $ (1.66) $ 0.87 $ 1.54 $ (4.76) (a) The sum of quarterly amounts, including per share amounts, may not equal amounts reported for year-to-date periods. This is due to the (b) effects of rounding and to changes in the number of weighted-average shares outstanding each period. Includes pretax asset impairment charge of $2.6 billion recorded in discontinued operations during the year ended December 31, 2012. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, for additional information. Ameren Missouri Quarter ended March 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . March 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . Operating revenues $ 796 691 889 844 1,093 1,064 763 673 Operating income $ 111 78 179 269 417 429 96 69 Net income (loss) $ 41 22 85 144 239 237 33 16 Ameren Illinois Quarter ended Operating revenues Operating income Net income March 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . March 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ June 30, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . December 31, 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . December 31, 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 684 724 516 564 547 648 564 589 $ 85 89 87 86 158 151 85 51 $ 32 28 32 33 77 71 22 12 Net income (loss) available to common stockholder $ 40 21 84 143 238 236 33 16 Net income available to common stockholder $ 31 27 31 32 77 71 21 11 ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE. None. 154 ITEM 9A. CONTROLS AND PROCEDURES. Each of the Ameren Companies was required to comply with Section 404 of the Sarbanes-Oxley Act of 2002 and related SEC regulations as to management’s assessment of internal control over financial reporting for the 2013 fiscal year. (a) Evaluation of Disclosure Controls and Procedures As of December 31, 2013, evaluations were performed under the supervision and with the participation of management, including the principal executive officer and 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, 2013, the principal executive officer and principal financial officer of each of the Ameren Companies concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in such registrant’s reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and such information is accumulated and communicated to its management, including its principal executive 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 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 (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO 1992). After making that evaluation, management concluded that each of the Ameren Companies’ internal control over financial reporting was effective as of December 31, 2013. The effectiveness of Ameren’s internal control over financial reporting as of December 31, 2013, 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, or 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 2013 that has not previously been reported on an SEC Form 8-K. 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 2014 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 2014 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 each of Ameren Missouri’s and Ameren Illinois’ definitive information statement: “Information Concerning Nominees to the Board of Directors,” “Section 16(a) Beneficial Ownership Reporting Compliance,” “Corporate Governance” and “Board Structure.” Information concerning executive officers of the Ameren Companies required by Item 401 of SEC Regulation S-K is reported under a separate caption entitled “Executive Officers of the Registrants” in Part I of this report. 155 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 have no securities listed on the NYSE and therefore are not subject to the NYSE listing standards. Walter J. Galvin serves as chairman of Ameren’s audit and risk committee, and Catherine S. Brune, Ellen M. Fitzsimmons and Stephen R. Wilson serve as members. The board of directors of Ameren has determined that Walter J. Galvin qualifies as an audit committee financial expert and that he 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 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.ameren.com. ITEM 11. EXECUTIVE COMPENSATION. To encourage ethical conduct in its financial management and reporting, Ameren has adopted a 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 each of the Ameren Companies. Ameren has also adopted a code of business conduct that applies to the directors, officers, and employees of the Ameren Companies. It is referred to as the Corporate Compliance Policy. The Ameren Companies make available free of charge through Ameren’s website (www.ameren.com) the Code of Ethics and the Corporate Compliance Policy. Any amendment to the Code of Ethics or the Corporate Compliance Policy and any waiver from a provision of the Code of Ethics or the Corporate Compliance Policy as it relates to the principal executive officer, the president, the principal financial officer, the principal accounting officer, the controller and 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. 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 2014 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 2014 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 each of Ameren Missouri’s and Ameren Illinois’ definitive information statement: “Executive Compensation” 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, 2013, with respect to the shares of Ameren’s common stock that may be issued under its existing equity compensation plans. Column A Column B Column C Number of Securities To Be Issued Upon Exercise of Outstanding Options, Warrants and Rights Weighted-Average Exercise Price of Outstanding Options, Warrants and Rights Number of Securities Remaining Available for Future Issuance Equity Compensation Plans (excluding securities reflected in Column A) Plan Category Equity compensation plans approved by security holders(a) . . . . . . . . . . . . . . . . . . . . . 2,509,073 Equity compensation plans not approved by security holders . . . . . . . . . . . . . . . . . . . . . . - Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2,509,073 (b) - (b) 627,648 - 627,648 (a) Consists of the Ameren Corporation 2006 Omnibus Incentive Compensation Plan, which was approved by shareholders in May 2006 and expires on May 2, 2016. Pursuant to grants of performance share units (PSUs) under the 2006 Omnibus Incentive Compensation Plan, 801,853 of the securities represent PSUs that vested as of December 31, 2013 (including accrued and reinvested dividends), and 1,653,280 of the securities represent target PSUs granted but not vested (including accrued and reinvested dividends) as of December 31, 2013. 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 total shareholder return objectives established for such awards. For additional information about the PSUs, including payout calculations, see “Compensation Discussion and Analysis – Long-Term Incentives: Performance Share Unit Program (PSUP)” in Ameren’s definitive proxy 156 statement for its 2014 annual meeting of shareholders filed pursuant to SEC Regulation 14A. 53,940 of the securities represent shares that may be issued as of December 31, 2013, to satisfy obligations under the Ameren Corporation Deferred Compensation Plan for members of the board of directors. (b) Earned PSUs and deferred compensation stock units are paid in shares of Ameren common stock on a one-for-one basis. Accordingly, the PSUs and deferred compensation stock units have been excluded for purposes of calculating the weighted-average exercise price. Ameren Missouri and Ameren Illinois do not have separate equity compensation plans. 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 2014 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 2014 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 Item 404 and Item 407(a) of SEC Regulation S-K for Ameren will be included in its definitive proxy statement for its 2014 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 2014 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 each of Ameren Missouri’s and Ameren Illinois’ definitive information statement: “Policy and Procedures With Respect to Related Person Transactions” and “Director Independence.” ITEM 14. PRINCIPAL ACCOUNTING 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 2014 annual meetings of stockholders 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: “Independent Registered Public Accounting Firm.” 157 PART IV ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES. (a)(1) Financial Statements Ameren Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Income (Loss) – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Comprehensive Income (Loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Balance Sheet – December 31, 2013 and 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Cash Flows – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated Statement of Stockholders’ Equity – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Income and Comprehensive Income – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . Balance Sheet – December 31, 2013 and 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Cash Flows – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Stockholders’ Equity – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Income and Comprehensive Income – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . Balance Sheet – December 31, 2013 and 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Cash Flows – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Statement of Stockholders’ Equity – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (a)(2) Financial Statement Schedules Schedule I – Condensed Financial Information of Parent – Ameren: Condensed Statement of Income (Loss) and Comprehensive Income (Loss) – Years Ended December 31, 2013, 2012, and 2011 . . . Condensed Balance Sheet – December 31, 2013 and 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Condensed Statement of Cash Flows – Years Ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Schedule II – Valuation and Qualifying Accounts for the years ended December 31, 2013, 2012, and 2011 . . . . . . . . . . . . . . . . . . . . . . . Page No. 70 72 73 74 75 76 71 77 78 79 80 71 81 82 83 84 159 159 160 161 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 commencing on page 165. Exhibits are listed in the Exhibit Index commencing on page 165. 158 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED STATEMENT OF INCOME (LOSS) AND COMPREHENSIVE INCOME (LOSS) For the Years Ended December 31, 2013, 2012 and 2011 (In millions) 2013 2012 2011 Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Operating loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity in earnings of subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest income from affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income tax (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net Income Attributable to Ameren Corporation – Continuing Operations . . . . . . . . . . . . . . . . . . . . . . . Net Income (Loss) Attributable to Ameren Corporation – Discontinued Operations . . . . . . . . . . . . . . . Net Income (Loss) Attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net Income Attributable to Ameren Corporation – Continuing Operations . . . . . . . . . . . . . . . . . . . . . . . Other Comprehensive Income (Loss), Net of Taxes: Pension and other postretirement benefit plan activity, net of income taxes (benefit) of $16, $(6), and $(14), respectively . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ Comprehensive Income from Continuing Operations Attributable to Ameren Corporation . . . . . . . . . . Net Income (Loss) Attributable to Ameren Corporation – Discontinued Operations . . . . . . . . . . . . . . . Other Comprehensive Income (Loss) from Discontinued Operations, Net of Income Taxes . . . . . . . . . Comprehensive Income (Loss) from Discontinued Operations Attributable to Ameren Corporation . . . Comprehensive Income (Loss) Attributable to Ameren Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . $ - 26 (26) 546 3 5 42 (36) 512 (223) 289 512 30 542 (223) (19) (242) 300 $ $ $ $ $ $ - 17 (17) 546 3 4 39 (27) 516 (1,490) (974) 516 (8) 508 (1,490) 50 (1,440) $ (932) $ - 13 (13) 464 5 4 41 (20) 431 88 519 431 (19) 412 88 (14) 74 486 (In millions) Assets: SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED BALANCE SHEET December 31, 2013 December 31, 2012 Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Advances to money pool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts and notes receivable – affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous accounts and notes receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in subsidiaries – continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in subsidiaries – discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Note receivable – affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated deferred income taxes, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other non-current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 11 334 27 125 42 539 6,336 (5) 51 623 141 $ 23 316 31 — 49 419 6,315 (353) 462 210 110 Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 7,685 $ 7,163 Liabilities and Stockholders’ Equity: Current maturities of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts payable – affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other deferred credits and liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 425 368 119 4 20 936 — 205 Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,141 Commitments and Contingencies Stockholders’ Equity: Common stock, $.01 par value, 400.0 shares authorized – shares outstanding of 242.6 . . . . . . . . . . . Other paid-in capital, principally premium on common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accumulated other comprehensive income (loss) Total stockholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 5,632 907 3 6,544 $ — — 3 10 30 43 424 80 547 2 5,616 1,006 (8) 6,616 Total liabilities and stockholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 7,685 $ 7,163 159 SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT AMEREN CORPORATION CONDENSED STATEMENT OF CASH FLOWS For the Years Ended December 31, 2013, 2012 and 2011 (In millions) Net cash flows provided by operating activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash flows from investing activities: Money pool advances, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Notes receivable – affiliates, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Investments in subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Distributions from subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net cash flows provided by (used in) investing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash flows from financing activities: Dividends on common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Short-term debt and credit facility borrowings, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Issuances of common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net cash flows used in financing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net change in cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents at the end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash dividends received from consolidated subsidiaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncash investing activity – divestiture . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Noncash financing activity – dividends on common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2013 2012 2011 $ 453 $ 532 $ 804 (371) (23) (50) 1 (2) (445) (388) 368 — (20) (12) 23 11 570 494 — $ $ $ $ 24 (20) (2) 21 (5) 18 (382) (148) — (530) 20 3 23 610 — (7) $ $ $ $ (276) 358 (94) 3 (5) (14) (375) (481) 65 (791) (1) 4 3 730 — — $ $ $ $ AMEREN CORPORATION (parent company only) NOTES TO CONDENSED FINANCIAL STATEMENTS December 31, 2013 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. In accordance with authoritative accounting guidance, Ameren Corporation (parent company only) has accounted for wholly owned subsidiaries using the equity method. These financial statements are presented on a condensed basis. Additional disclosures relating to the parent company financial statements are included within the combined notes under Part II, Item 8, of this report. NOTE 2 – SHORT-TERM DEBT AND LIQUIDITY 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 3 – LONG-TERM OBLIGATIONS See Note 5 – Long-term Debt and Equity Financings under Part II, Item 8, of this report for a description and details of long-term obligations of Ameren Corporation (parent company only). NOTE 4 – COMMITMENTS AND CONTINGENCIES See Note 15 – Commitments and Contingencies and Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for a description of all material contingencies and guarantees outstanding of Ameren Corporation (parent company only). NOTE 5 – NEW AER DIVESTITURE AND DISCONTINUED OPERATIONS In December 2012, Ameren determined that it intended to, and it was probable that it would, exit its Merchant Generation business before the end of the previously estimated useful lives of that business’s long-lived assets. As a result of the 2012 determination, Ameren Corporation (parent company only) recorded a pretax impairment charge of $1.88 billion to reduce its investment in certain of the Merchant Generation segment’s coal and natural gas-fired energy centers to their estimated fair 160 values. On December 2, 2013, Ameren completed a divestiture that included a significant portion of that business. As a result of the divestiture in 2013, Ameren Corporation (parent company only) recorded a pretax loss on disposal of $201 million. These charges were included within “Net Income (Loss) Attributable to Ameren Corporation – Discontinued Operations” in the Ameren Corporation (parent company only) Condensed Statement of Income (Loss) and Comprehensive Income (Loss) for the years ended December 31, 2013, and 2012. The “Miscellaneous accounts and notes receivable” on the December 31, 2013 Ameren Corporation (parent company only) Condensed Balance Sheet included a receivable from Dynegy related to the non-state-regulated subsidiary money pool borrowing balance as of the divestiture date of certain New AER subsidiaries. Additionally, a payable to Dynegy of the estimated working capital adjustment required under the terms of the agreement with IPH is reflected in “Accounts payable” on the December 31, 2013, Ameren Corporation (parent company only) Condensed Balance Sheet. Assuming IPH and Ameren reach an agreement, both the receivable and the payable will be finalized within 120 days after the closing of the divestiture. See Note 16 – Divestiture Transactions and Discontinued Operations under Part II, Item 8, of this report for additional information on the impairment charges recognized in 2013 and 2012 as well as the divestiture. (in millions) Column A Column B Column C Column D Column E SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS FOR THE YEARS ENDED DECEMBER 31, 2013, 2012 AND 2011 Description Ameren: Deducted from assets – allowance for doubtful accounts: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred tax valuation allowance: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Missouri: Deducted from assets – allowance for doubtful accounts: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred tax valuation allowance: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ameren Illinois: Deducted from assets – allowance for doubtful accounts: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred tax valuation allowance: 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2011 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Balance at Beginning of Period (1) Charged to Costs and Expenses (2) Charged to Other Accounts(a) Deductions(b) Balance at End of Period $ $ $ $ $ $ 17 20 23 2 1 1 5 7 8 1 1 1 12 13 13 1 - - $ $ $ $ $ $ 35 30 41 5 1 - 16 11 17 - - - 19 19 24 - 1 - $ $ $ $ $ $ 4 2 - - - - - - - - - - 4 2 - - - - $ $ $ $ $ $ 38 35 44 - - - 16 13 18 - - - 22 22 24 - - - $ $ $ $ $ $ 18 17 20 7 2 1 5 5 7 1 1 1 13 12 13 1 1 - (a) Uncollectible account reserve associated with receivables purchased by Ameren Illinois from alternative retail electric suppliers, as required by the Illinois Public Utilities Act. (b) Uncollectible accounts charged off, less recoveries. 161 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: March 3, 2014 AMEREN CORPORATION (registrant) By /s/ Thomas R. Voss Thomas R. Voss Chairman 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/ Thomas R. Voss Thomas R. Voss /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. /s/ Bruce A. Steinke Bruce A. Steinke Warner L. Baxter Catherine S. Brune Ellen M. Fitzsimmons Walter J. Galvin Richard J. Harshman Gayle P.W. Jackson James C. Johnson Steven H. Lipstein Patrick T. Stokes Stephen R. Wilson * * * * * * * * * * * Jack D. Woodard *By /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. Attorney-in-Fact Chairman and Chief Executive Officer, and Director (Principal Executive Officer) 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 162 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 Date: March 3, 2014 UNION ELECTRIC COMPANY (registrant) By /s/ Warner L. Baxter Warner L. Baxter Chairman, 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/ Warner L. Baxter Warner L. Baxter /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. /s/ Bruce A. Steinke Bruce A. Steinke Daniel F. Cole Michael L. Moehn Charles D. Naslund * * * * Gregory L. Nelson *By /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. Attorney-in-Fact March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 Chairman, President and Chief Executive Officer, and Director (Principal Executive Officer) Executive Vice President and Chief Financial Officer, and Director (Principal Financial Officer) Senior Vice President, Finance and Chief Accounting Officer (Principal Accounting Officer) Director Director Director Director 163 Date: March 3, 2014 AMEREN ILLINOIS COMPANY (registrant) By /s/ Richard J. Mark Richard J. Mark Chairman, 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/ Richard J. Mark Richard J. Mark /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. /s/ Bruce A. Steinke Bruce A. Steinke Daniel F. Cole Chairman, President and Chief Executive Officer, and Director (Principal Executive Officer) Executive Vice President and Chief Financial Officer, and Director (Principal Financial Officer) Senior Vice President, Finance and Chief Accounting Officer (Principal Accounting Officer) * * Director Director Gregory L. Nelson *By /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. Attorney-in-Fact March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 March 3, 2014 164 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: Plan of Acquisition, Reorganization, Arrangement, Liquidation or Succession Ameren Illinois Agreement and Plan of Merger, dated as of April 13, 2010, among CIPS, CILCO and IP 2.1 2.2 Ameren Annex A to Part I of the Registration Statement on Form S-4, File No. 333-166095). March 19, 2013 Form 8-K, Exhibit 2.1, File No. 1-14756 December 4, 2013 Form 8-K, Exhibit 2.2, File No. 1-14756 Transaction Agreement, dated as of March 14, 2013, between Ameren Corporation and Illinois Power Holdings, LLC Letter Agreement, dated December 2, 2013, between Ameren Corporation and Illinois Power Holdings, LLC, amending the Transaction Agreement, dated as of March 14, 2013 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 Certificate of Amendment to Ameren’s Restated Articles of Incorporation filed April 21, 2011 Certificate of Amendment to Ameren’s Restated Articles of Incorporation filed December 18, 2012 1998 Form 10-K, Exhibit 3(i), File No. 1-14756 April 21, 2011 Form 8-K, Exhibit 3(i), File No. 1-14756 December 18, 2012 Form 8-K, Exhibit 3.1(i), File No. 1-14756 2.3 Ameren Articles of Incorporation/ By-Laws 3.1(i) 3.2(i) Ameren Ameren 3.3(i) Ameren 3.4(i) Ameren 3.5(i) 3.6(i) Ameren Missouri Ameren Illinois 3.7(ii) Ameren Restated Articles of Incorporation of Ameren Missouri 1993 Form 10-K, Exhibit 3(i), File No. 1-2967 Restated Articles of Incorporation of Ameren Illinois 2010 Form 10-K, Exhibit 3.4(i), File No. 1-3672 By-Laws of Ameren, as amended December 14, 2012 December 18, 2012 Form 8-K, Exhibit 3.1(ii), File No. 1-14756 3.8(ii) Ameren Missouri By-Laws of Ameren Missouri, as amended December 10, 2010 December 15, 2010 Form 8-K, Exhibit 3.1(ii), File No. 1-2967 3.9(ii) Ameren Illinois Bylaws of Ameren Illinois, as amended December 10, 2010 December 15, 2010 Form 8-K, Exhibit 3.2(ii), File No. 1-3672 Instruments Defining Rights of Security Holders, Including Indentures 4.1 Ameren 4.2 4.3 Ameren Ameren 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 May 15, 2009, establishing 8.875% Senior Notes, due 2014 (including the global note) May 15, 2009 Form 8-K, Exhibits 4.3 and 4.4, File No. 1-14756 165 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 4.4 4.5 4.6 4.7 4.8 4.9 4.10 4.11 4.12 4.13 4.14 4.15 4.16 4.17 4.18 4.19 4.20 4.21 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 Exhibit B-1, File No. 2-4940 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 Supplemental Indenture to the Ameren Missouri Mortgage dated as of July 1, 1956 August 2, 1956 Form 8-K, Exhibit 2, File No. 1-2967 Supplemental Indenture to the Ameren Missouri Mortgage dated as of April 1, 1971 Supplemental Indenture to the Ameren Missouri Mortgage dated as of February 1, 1974 Supplemental Indenture to the Ameren Missouri Mortgage dated as of July 7, 1980 Supplemental Indenture to the Ameren Missouri Mortgage dated as of October 1, 1993, relative to Series 2028 Supplemental Indenture to the Ameren Missouri Mortgage dated as of February 1, 2000 April 1971 Form 8-K, Exhibit 6, File No. 1-2967 February 1974 Form 8-K, Exhibit 3, File No. 1-2967 Exhibit 4.6, File No. 2-69821 1993 Form 10-K, Exhibit 4.8, File No. 1-2967 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 Supplemental Indenture to the Ameren Missouri Mortgage dated April 1, 2003, relative to Series CC Supplemental Indenture to the Ameren Missouri Mortgage dated July 15, 2003, relative to Series DD Supplemental Indenture to the Ameren Missouri Mortgage dated October 1, 2003, relative to Series EE Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004, relative to Series 2004A (1998A) Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004, relative to Series 2004B (1998B) Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004, relative to Series 2004C (1998C) Supplemental Indenture to the Ameren Missouri Mortgage dated February 1, 2004, relative to Series 2004H (1992) Supplemental Indenture to the Ameren Missouri Mortgage dated May 1, 2004 relative to Series FF Supplemental Indenture to the Ameren Missouri Mortgage dated September 1, 2004 relative to Series GG 166 March 11, 2003 Form 8-K, Exhibit 4.4, File No. 1-2967 April 10, 2003 Form 8-K, Exhibit 4.4, File No. 1-2967 August 4, 2003 Form 8-K, Exhibit 4.4, File No. 1-2967 October 8, 2003 Form 8-K, Exhibit 4.4, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.1, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.2, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.3, File No. 1-2967 March 31, 2004 Form 10-Q, Exhibit 4.8, File No. 1-2967 May 18, 2004 Form 8-K, Exhibit 4.4, File No. 1-2967 September 23, 2004 Form 8-K, Exhibit 4.4, File No. 1-2967 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 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 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 January 1, 2005 relative to Series HH January 27, 2005 Form 8-K, Exhibit 4.4, File No. 1-2967 July 21, 2005 Form 8-K, Exhibit 4.4, File No. 1-2967 December 9, 2005 Form 8-K, Exhibit 4.4, File No. 1-2967 June 15, 2007 Form 8-K, Exhibit 4.5, File No. 1-2967 April 8, 2008 Form 8-K, Exhibit 4.7, File No. 1-2967 June 19, 2008 Form 8-K, Exhibit 4.5, File No. 1-2967 March 23, 2009 Form 8-K, Exhibit 4.5, File No. 1-2967 Exhibit 4.45, File No. 333-182258 September 11, 2012 Form 8-K, Exhibit 4.4, File No. 1-2967 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 Supplemental Indenture to the Ameren Missouri Mortgage dated July 1, 2005 relative to Series II Supplemental Indenture to the Ameren Missouri Mortgage dated December 1, 2005 relative to Series JJ Supplemental Indenture to the Ameren Missouri Mortgage dated June 1, 2007 relative to Series KK Supplemental Indenture to the Ameren Missouri Mortgage dated April 1, 2008 relative to Series LL Supplemental Indenture to the Ameren Missouri Mortgage dated June 1, 2008 relative to Series MM Supplemental Indenture to the Ameren Missouri Mortgage dated March 1, 2009 relative to Series NN Supplemental Indenture to the Ameren Missouri Mortgage dated May 15, 2012 Supplemental Indenture to the Ameren Missouri Mortgage dated September 1, 2012 relative to Series OO 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 167 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 4.37 4.38 4.39 4.40 4.41 4.42 4.43 4.44 4.45 4.46 4.47 4.48 4.49 4.50 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 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 April 10, 2003 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 August 4, 2003 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 October 8, 2003 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 May 18, 2004 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 September 23, 2004 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 January 27, 2005 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 December 9, 2005 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 June 15, 2007 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2967 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 April 9, 2003, establishing the 4.75% Senior Secured Notes due 2015 (including the global note) Ameren Missouri Indenture Company Order dated July 28, 2003, establishing the 5.10% Senior Secured Notes due 2018 (including the global note) Ameren Missouri Indenture Company Order dated October 7, 2003, establishing the 4.65% Senior Secured Notes due 2013 (including the global note) Ameren Missouri Indenture Company Order dated May 13, 2004, establishing the 5.50% Senior Secured Notes due 2014 (including the global note) Ameren Missouri Indenture Company Order dated September 1, 2004, establishing the 5.10% Senior Secured Notes due 2019 (including the global note) Ameren Missouri Indenture Company Order dated January 27, 2005, establishing the 5.00% Senior Secured Notes due 2020 (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 December 8, 2005, establishing the 5.40% Senior Secured Notes due 2016 (including the global note) Ameren Missouri Indenture Company Order dated June 15, 2007, establishing the 6.40% Senior Secured Notes due 2017 (including the global note) 168 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 4.51 4.52 4.53 4.54 4.55 4.56 4.57 4.58 4.59 4.60 4.61 4.62 4.63 4.64 Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Missouri Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois April 8, 2008 Form 8-K, Exhibits 4.3 and 4.5, File No. 1-2967 June 19, 2008 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 Exhibit 4.4, File No. 333-59438 Ameren Missouri Indenture Company Order dated April 8, 2008, establishing the 6.00% Senior Secured Notes due 2018 (including the global note) Ameren Missouri Indenture Company Order dated June 19, 2008, establishing the 6.70% Senior Secured Notes due 2019 (including the global note) Ameren Missouri Indenture Company Order dated March 20, 2009, establishing 8.45% Senior Secured Notes due 2039 (including the global note) Ameren Missouri Indenture Company Order dated September 11, 2012, establishing 3.90% Senior Secured Notes due 2042 (including the global note) Indenture dated as of December 1, 1998, from Central Illinois Public Service Company (now known as Ameren Illinois) to The Bank of New York Mellon Trust Company, N.A., as successor trustee (CIPS Indenture) 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 Ameren Illinois Global Note, dated October 1, 2010, representing CIPS Indenture Senior Notes, 6.125% due 2028 2010 Form 10-K, Exhibit 4.60, File No. 1-3672 2010 Form 10-K, Exhibit 4.62, File No. 1-3672 Exhibit B-1, Registration No. 2-1937; Exhibit B-1(a), Registration No. 2-2093; and Exhibit A, April 1940 Form 8-K, File No. 1-2732 Ameren Illinois Global Note, dated October 1, 2010, representing CIPS Indenture Senior Notes, 6.70% Series Secured Notes due 2036 Indenture of Mortgage and Deed of Trust between Illinois Power Company (predecessor in interest to CILCO and Ameren Illinois) and Bankers Trust Company (now known as Deutsche Bank Trust Company Americas), as trustee, dated as of April 1, 1933 (CILCO Mortgage), Supplemental Indenture between the same parties dated as of June 30, 1933, Supplemental Indenture between CILCO (predecessor in interest to Ameren Illinois) and the trustee, dated as of July 1, 1933, Supplemental Indenture between the same parties dated as of January 1, 1935, and Supplemental Indenture between the same parties dated as of April 1, 1940 Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois Supplemental Indenture to the CILCO Mortgage, dated December 1, 1949 December 1949 Form 8-K, Exhibit A, File No. 1-2732 Supplemental Indenture to the CILCO Mortgage, dated July 1, 1957 July 1957 Form 8-K, Exhibit A, File No. 1-2732 Supplemental Indenture to the CILCO Mortgage, dated February 1, 1966 February 1966 Form 8-K, Exhibit A, File No. 1-2732 169 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 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 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 Supplemental Indenture to the CILCO Mortgage, dated January 15, 1992 January 30, 1992 Form 8-K, Exhibit 4(b), File No. 1-2732 Supplemental Indenture to the CILCO Mortgage, dated June 1, 2006 for the Series AA and BB Supplemental Indenture to the CILCO Mortgage, dated December 1, 2008 for the Series CC June 19, 2006 Form 8-K, Exhibit 4.11, File No. 1-2732 December 9, 2008 Form 8-K, Exhibit 4.5, File No. 1-2732 Supplemental Indenture to the CILCO Mortgage, dated as of October 1, 2010 October 7, 2010 Form 8 K, Exhibit 4.4, File No. 1-14756 Indenture dated as of June 1, 2006, from CILCO (predecessor in interest to Ameren Illinois) to The Bank of New York Mellon Trust Company, N.A., as successor trustee (CILCO Indenture) June 19, 2006 Form 8-K, Exhibit 4.3, File No. 1-2732 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 CILCO Indenture Company Order, dated June 14, 2006, establishing the 6.20% Senior Secured Notes due 2016 (including the global note) and the 6.70% Senior Secured Notes due 2036 (including the global note) CILCO Indenture Company Order, dated December 9, 2008, establishing the 8.875% Senior Secured Notes due 2013 (including the global note) General Mortgage Indenture and Deed of Trust dated as of November 1, 1992 between Illinois Power Company (predecessor in interest to Ameren Illinois) and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Ameren Illinois Mortgage) Supplemental Indenture dated as of March 1, 1998, to Ameren Illinois Mortgage for Series S Supplemental Indenture dated as of March 1, 1998, to Ameren Illinois Mortgage for Series T Supplemental Indenture amending the Ameren Illinois Mortgage dated as of June 15, 1999 Supplemental Indenture dated as of July 15, 1999, to Ameren Illinois Mortgage for Series U Supplemental Indenture amending the Ameren Illinois Mortgage dated as of December 15, 2002 Supplemental Indenture dated as of June 1, 2006, to Ameren Illinois Mortgage for Series AA Supplemental Indenture dated as of November 15, 2007, to Ameren Illinois Mortgage for Series BB 170 June 19, 2006 Form 8-K, Exhibit 4.6, File No. 1-2732 December 9, 2008 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-2732 1992 Form 10-K, Exhibit 4(cc), File No. 1-3004 Exhibit 4.41, File No. 333-71061 Exhibit 4.42, File No. 333-71061 June 30, 1999 Form 10-Q, Exhibit 4.2, File No. 1-3004 June 30, 1999 Form 10-Q, Exhibit 4.4, File No. 1-3004 December 23, 2002 Form 8-K, Exhibit 4.1, File No. 1-3004 June 19, 2006 Form 8-K, Exhibit 4.13, File No. 1-3004 November 20, 2007 Form 8-K, Exhibit 4.4, File No. 1-3004 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 4.82 4.83 4.84 4.85 4.86 4.87 4.88 4.89 4.90 4.91 4.92 4.93 4.94 4.95 4.96 4.97 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 Supplemental Indenture dated as of April 1, 2008, to Ameren Illinois Mortgage for Series CC Supplemental Indenture dated as of October 1, 2008, to Ameren Illinois Mortgage for Series DD Supplemental Indenture, dated as of October 1, 2010, to Ameren Illinois Mortgage for Series CIPS-AA, CIPS-BB and CIPS-CC Supplemental Indenture, dated as of January 15, 2011, to Ameren Illinois Mortgage Supplemental Indenture dated as of August 1, 2012, to Ameren Illinois Mortgage for Series EE Supplemental Indenture, dated as of December 1, 2013, to Ameren Illinois Mortgage for Series FF Indenture, dated as of June 1, 2006 from IP (predecessor in interest to Ameren Illinois) 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, CIPS-BB and CIPS-CC Second Supplemental Indenture to the Ameren Illinois Indenture dated as of July 21, 2011 Third Supplemental Indenture to the Ameren Illinois Indenture dated as of May 15, 2012 Ameren Illinois Indenture Company Order, dated June 14, 2006, establishing the 6.25% Senior Secured Notes due 2016 (including the global note) Ameren Illinois Indenture Company Order, dated November 15, 2007, establishing 6.125% Senior Secured Notes due 2017 (including the global note) Ameren Illinois Indenture Company Order, dated April 8, 2008, establishing 6.25% Senior Secured Notes due 2018 (including the global note) Ameren Illinois Indenture Company Order dated October 23, 2008, establishing 9.75% Senior Secured Notes due 2018 (including the global note) Ameren Illinois Indenture Company Order dated August 20, 2012, establishing 2.70% Senior Secured Notes due 2022 (including the global note) Ameren Illinois Indenture Company Order dated December 10, 2013, establishing 4.80% Senior Secured Notes due 2043 (including the global note) 171 April 8, 2008 Form 8-K, Exhibit 4.9, File No. 1-3004 October 23, 2008 Form 8-K, Exhibit 4.4, File No. 1-3004 October 7, 2010 Form 8 K, Exhibit 4.9, File No. 1-3672 Exhibit 4.78, File No. 333-182258 August 20, 2012 Form 8-K, Exhibit 4.4, File No. 1-3672 December 10, 2013 Form 8-K, Exhibit 4.5, File No. 1-3672 June 19, 2006 Form 8-K, Exhibit 4.4, File No. 1-3004 October 7, 2010 Form 8 K, Exhibit 4.5, File No. 1-14756 September 30, 2011 Form 10-Q, Exhibit 4.2, File No. 1-3672 Exhibit 4.83, File No. 333-182258 June 19, 2006 Form 8-K, Exhibit 4.7, File No. 1-3004 November 20, 2007 Form 8-K, Exhibit 4.2, File No. 1-3004 April 8, 2008 Form 8-K, Exhibit 4.4, File No. 1-3004 October 23, 2008 Form 8-K, Exhibit 4.2, File No. 1-3004 August 20, 2012 Form 8-K, Exhibits 4.2 and 4.3, File No. 1-3004 December 10, 2013 Form 8-K, Exhibit 4.2, File No. 1-3672 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: Material Contracts 10.1 Ameren Ameren Illinois 10.2 Ameren Companies 10.3 10.4 Ameren Ameren Missouri Ameren Ameren Illinois 10.5 Ameren 10.6 Ameren 10.7 Ameren Companies 10.8 Ameren Companies 10.9 Ameren Companies Unilateral Borrowing Agreement by and among Ameren, IP (predecessor in interest to Ameren Illinois) and Ameren Services, dated as of September 30, 2004 Third Amended Ameren Corporation System Utility Money Pool Agreement, as amended September 30, 2004 Credit Agreement, dated as of November 14, 2012, by and among Ameren, Ameren Missouri and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto. Credit Agreement, dated as of November 14, 2012, by and among Ameren, Ameren Illinois and JPMorgan Chase Bank, N.A., as agent, and the lenders party thereto. *Summary Sheet of Ameren Corporation Non- Management Director Compensation revised on August 9, 2013 and effective as of August 12, 2013 *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 *Amendment dated October 14, 2010, to Ameren’s Deferred Compensation Plan for Members of the Board of Directors *Ameren’s Deferred Compensation Plan as amended and restated effective January 1, 2010 October 1, 2004 Form 8-K, Exhibit 10.3, File No. 1-3004 October 1, 2004 Form 8-K, Exhibit 10.2, File No. 1-14756 November 15, 2012 Form 8-K, Exhibit 10.1, File No. 1-14756 November 15, 2012 Form 8-K, Exhibit 10.2, File No. 1-14756 September 30, 2013 Form 10-Q, Exhibit 10.1, File No. 1-14756 June 30, 2008 Form 10-Q, Exhibit 10.3, File No. 1-14756 2009 Form 10-K, Exhibit 10.15 , File No. 1-14756 2010 Form 10-K, Exhibit 10.15, File No. 1-14756 October 14, 2009 Form 8-K, Exhibit 10.1, File No. 1-14756 10.10 Ameren Companies *Amendment dated October 14, 2010 to Ameren’s Deferred Compensation Plan 2010 Form 10-K, Exhibit 10.17, File No. 1-14756 10.11 Ameren Companies *2012 Ameren Executive Incentive Plan 10.12 Ameren Companies *2013 Ameren Executive Incentive Plan 10.13 Ameren Companies 10.14 Ameren Companies 10.15 Ameren Companies 10.16 Ameren Companies 10.17 Ameren Companies 10.18 Ameren Companies *2012 Base Salary Table for Named Executive Officers *2013 Base Salary Table for Named Executive Officers *2014 Base Salary Table for Named Executive Officers *Second Amended and Restated Ameren Corporation Change of Control Severance Plan *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 172 December 14, 2011 Form 8-K, Exhibit 10.1, File No. 1-14756 December 18, 2012 Form 8-K, Exhibit 10.1, File No. 1-14756 2011 Form 10-K, Exhibit 10.23, File No. 1-14756 2012 Form 10-K, Exhibit 10.17, File No. 1-14756 2008 Form 10-K, Exhibit 10.37, File No. 1-14756 October 14, 2009 Form 8-K, Exhibit 10.2, File No. 1-14756 September 30, 2013 Form 10-Q, Exhibit 10.2, File No. 1-14756 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 10.19 Ameren Companies 10.20 Ameren Companies 10.21 Ameren Companies *Formula for Determining 2011 Target Performance Share Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2012 Target Performance Share Unit Awards to be Issued to Named Executive Officers *Formula for Determining 2013 Target Performance Share Unit Awards to be Issued to Named Executive Officers December 15, 2010 Form 8-K, Exhibit 99.1, File No. 1-14756 December 14, 2011 Form 8-K, Exhibit 99.1, File No. 1-14756 December 18, 2012 Form 8-K, Exhibit 99.1, File No. 1-14756 10.22 Ameren Companies *Ameren Corporation 2006 Omnibus Incentive Compensation Plan February 16, 2006 Form 8-K, Exhibit 10.3, File No. 1-14756 10.23 Ameren Companies 10.24 Ameren Companies 10.25 Ameren Companies 10.26 Ameren Companies 10.27 Ameren Companies 10.28 Ameren Companies 10.29 10.30 10.31 Ameren Ameren Illinois Ameren Ameren Illinois Ameren Ameren Illinois 10.32 Ameren 10.33 Ameren Statement re: Computation of Ratios 12.1 12.2 Ameren Ameren Missouri 12.3 Ameren Illinois *Form of Performance Share Unit Award Agreement for Awards Issued in 2011 pursuant to 2006 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2012 pursuant to 2006 Omnibus Incentive Compensation Plan *Form of Performance Share Unit Award Agreement for Awards Issued in 2013 pursuant to 2006 Omnibus Incentive Compensation Plan *Performance Stock Bonus Award Agreement, dated March 1, 2011, between Ameren and Adam C. Heflin *Ameren Supplemental Retirement Plan amended and restated effective January 1, 2008, dated June 13, 2008 *First Amendment to amended and restated Ameren Supplemental Retirement Plan, dated October 24, 2008 December 15, 2010 Form 8-K, Exhibit 10.2, File No. 1-14756 December 14, 2011 Form 8-K, Exhibit 10.2, File No. 1-14756 December 18, 2012 Form 8-K, Exhibit 10.2, File No. 1-14756 March 31, 2011 Form 10-Q, Exhibit 10.1, File No. 1-14756 June 30, 2008 Form 10-Q, Exhibit 10.1, File No. 1-14756 2008 Form 10-K, Exhibit 10.44, File No. 1-14756 *CILCO Executive Deferral Plan as amended effective August 15, 1999 1999 Form 10-K, Exhibit 10, File No. 1-2732 *CILCO Executive Deferral Plan II as amended effective April 1, 1999 1999 Form 10-K, Exhibit 10(a), File No. 1-2732 *CILCO Restructured Executive Deferral Plan (approved August 15, 1999) 1999 Form 10-K, Exhibit 10(e), File No. 1-2732 March 19, 2013 Form 8-K, Exhibit 10.3, File No. 1-14756 March 19, 2013 Form 8-K, Exhibit 10.4, File No. 1-14756 Novation and Amendment of Put Option Agreement, dated March 14, 2013, by and among Medina Valley, AERG, Genco and Ameren *Employment and Change of Control Agreement, dated March 13, 2013, between Steven R. Sullivan, AER and Ameren Ameren’s Statement of Computation of Ratio of Earnings to Fixed Charges Ameren Missouri’s Statement of Computation of Ratio of Earnings to Fixed Charges and Combined Fixed Charges and Preferred Stock Dividend Requirements Ameren Illinois’ Statement of Computation of Ratio of Earnings to Fixed Charges and Combined Fixed Charges and Preferred Stock Dividend Requirements 173 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: Code of Ethics 14.1 Ameren Companies Code of Ethics, as amended February 8, 2013 2012 Form 10-K, Exhibit 14.1, File No. 1-14756 Subsidiaries of the Registrant 21.1 Ameren Companies Subsidiaries of Ameren Consent of Experts and Counsel 23.1 23.2 Ameren Ameren Missouri 23.3 Ameren Illinois Power of Attorney 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 24.1 24.2 24.3 Ameren Powers of Attorney with respect to Ameren Ameren Missouri Ameren Illinois Power of Attorney with respect to Ameren Missouri Power of Attorney with respect to Ameren Illinois Rule 13a-14(a)/15d-14(a) Certifications 31.1 31.2 31.3 Ameren Ameren Ameren Missouri 31.4 Ameren Missouri 31.5 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 31.6 Ameren Illinois Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren Illinois Section 1350 Certifications 32.1 Ameren 32.2 Ameren Missouri 32.3 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 Additional Exhibits 99.1 Ameren Companies Amended and Restated Tax Allocation Agreement, dated as of November 21, 2013 Interactive Data File 101.INS** Ameren Companies XBRL Instance Document 101.SCH** Ameren Companies XBRL Taxonomy Extension Schema Document 174 Exhibit Designation Registrant(s) Nature of Exhibit Previously Filed as Exhibit to: 101.CAL** Ameren Companies 101.LAB** Ameren Companies 101.PRE** Ameren Companies 101.DEF** 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 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. **Attached as Exhibit 101 to this report is the following financial information for each of the Ameren Companies’ Annual Report on Form 10-K for the year ended December 31, 2013, formatted in XBRL (eXtensible Business Reporting Language): (i) the Consolidated Statement of Income (Loss) for the years ended December 31, 2013, 2012, and 2011, (ii) the Consolidated Statement of Comprehensive Income (Loss) for the years ended December 31, 2013, 2012 and 2011, (iii) the Consolidated Balance Sheet at December 31, 2013, and December 31, 2012, (iv) the Consolidated Statement of Cash Flows for the years ended December 31, 2013, 2012, and 2011, (v) the Consolidated Statement of Stockholders’ Equity for the years ended December 31, 2013, 2012, and 2011, and (vi) the Combined Notes to the Financial Statements for the year ended December 31, 2013. 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 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, Thomas R. Voss, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Thomas R. Voss Thomas R. Voss Chairman 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, Martin J. Lyons, Jr., certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. 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, Warner L. Baxter, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Warner L. Baxter Warner L. Baxter Chairman, President and Chief Executive Officer (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, Martin J. Lyons, Jr., certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. Executive Vice President and Chief Financial Officer (Principal Financial Officer) 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) Exhibit 31.5 I, Richard J. Mark, certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Richard J. Mark Richard J. Mark Chairman, President and Chief Executive Officer (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, Martin J. Lyons, Jr., certify that: 1. I have reviewed this report on Form 10-K for the fiscal year ended December 31, 2013, 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) b) 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 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: March 3, 2014 /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. 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, 2013, 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) 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 (2) 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: March 3, 2014 /s/ Thomas R. Voss Thomas R. Voss Chairman and Chief Executive Officer (Principal Executive Officer) /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. 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, 2013, 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) 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 (2) 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: March 3, 2014 /s/ Warner L. Baxter Warner L. Baxter Chairman, President and Chief Executive Officer (Principal Executive Officer) /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. 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, 2013, 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) 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 (2) 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: March 3, 2014 /s/ Richard J. Mark Richard J. Mark Chairman, President and Chief Executive Officer (Principal Executive Officer) /s/ Martin J. Lyons, Jr. Martin J. Lyons, Jr. Executive Vice President and Chief Financial Officer (Principal Financial Officer) INVESTOR INFORMATION Common Stock and Dividend Information Ameren’s common stock is listed on the New York Stock Exchange (ticker symbol: AEE). Ameren began trading on January 2, 1998, following the merger of Union Electric Company and CIPSCO Inc. on December 31, 1997. Ameren common shareholders of record totaled 57,623 on January 31, 2014. The following table provides the price ranges, closing prices and dividends declared per Ameren common share for each quarter of 2013 and 2012. AEE 2013 Quarter Ended High Low Close Dividends Declared $35.12 36.74 36.70 37.31 $30.64 32.34 32.61 34.18 $35.02 34.44 34.84 36.16 40 ¢ 40 40 40 March 31 June 30 September 30 December 31 AEE 2012 Quarter Ended High Low Close Dividends Declared March 31 June 30 September 30 December 31 $33.68 34.04 35.30 33.21 $30.89 31.15 32.27 28.43 $32.58 33.54 32.67 30.72 40 ¢ 40 40 40 Corporate Governance Documents Ameren makes available, free of charge through its website (Ameren.com), the charters of the Board of Directors’ Audit and Risk Committee, Human Resources Committee, Nominating and Corporate Governance Committee, Finance Committee and Nuclear Oversight and Environmental Committee. Also available on Ameren’s website are its corporate governance guidelines, policy regarding nominations of directors, policy regarding communications to the Board of Directors, policy and procedures with respect to related person transactions, code of business conduct (referred to as the “Corporate Compliance Policy”) and code of ethics for principal executive and senior ﬁ nancial ofﬁ cers. These documents are also available in print, free of charge upon written request, from the Ofﬁ ce of the Secretary, Ameren Corporation, P.O. Box 66149, Mail Code 1370, St. Louis, MO 63166-6149. Ameren also makes available, free of charge through its website, the company’s annual reports on SEC Form 10-K, quarterly reports on SEC Form 10-Q, and its current reports on SEC Form 8-K, including any chief executive ofﬁ cer and chief ﬁ nancial ofﬁ cer certiﬁ cations required to be ﬁ led with the Securities and Exchange Commission therewith. Online Stock Account Access Ameren’s website (Ameren.com) allows registered shareholders to access their account information online. Shareholders can securely change their reinvestment options, view account summaries, receive DRPlus statements and more through the website. This is a free service. Annual Meeting The annual meeting of Ameren Corporation shareholders will convene Investor Services Ameren’s Investor Services representatives are available to help you at 9 a.m. (Central Time), Thursday, April 24, 2014, at the Saint Louis Art each business day from 8 a.m. to 4 p.m. (Central Time). Please write Museum, One Fine Arts Drive, Forest Park, St. Louis, MO, 63110. The or call: annual shareholder meetings of Ameren Illinois Company and Union Electric Company will be held at the same time. DRPlus Any person of legal age or entity, whether or not an Ameren shareholder, is eligible to participate in DRPlus, Ameren’s dividend reinvestment and stock purchase plan. Participants can: • Make cash investments by check or automatic direct debit from their bank accounts to purchase Ameren common stock, up to a maximum of $120,000 annually; • Reinvest their dividends in Ameren common stock (the minimum dividend reinvestment requirement is 10%), per share; and • Place Ameren common stock certiﬁ cates in safekeeping and receive regular account statements. For more information about DRPlus, you may obtain a prospectus from Ameren’s Investor Services representatives. Direct Deposit of Dividends All registered Ameren common and Ameren Illinois Company and Union Electric Company preferred shareholders can have their cash dividends automatically deposited to 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. Ameren Services Company, Investor Services P.O. Box 66887 St. Louis, MO 63166-6887 314.554.3502 or 800.255.2237 invest@ameren.com Transfer Agent, Registrar and Paying Agent The Transfer Agent, Registrar and Paying Agent for Ameren common stock and Ameren Illinois Company and Union Electric Company preferred stock is Ameren Services Company. Ofﬁ ce Ameren Corporation One Ameren Plaza 1901 Chouteau Avenue St. Louis, MO 63103 314.621.3222 44607_CvrA.indd 4-6 2/25/14 11:42 PM P.O. Box 66149 | St. Louis, MO 63166-6149 Ameren.com 44607_CvrA.indd 1-3 2/28/14 12:27 AM

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