Ameren Illinois Co - Quarter Report: 2020 March (Form 10-Q)

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regulatory, judicial, or legislative actions, and any changes in regulatory policies and ratemaking determinations, that may change regulatory recovery mechanisms, such as those that may result from a rehearing of the November 2019 FERC order determining the allowed base ROE under the MISO tariff, the Notices of Inquiry issued by the FERC in March 2019, the Notice of Proposed Rulemaking issued by the FERC in March 2020, Ameren Illinois’ April 2020 annual electric distribution formula rate update filing, Ameren Illinois’ natural gas delivery service regulatory rate review filed with the ICC in February 2020, and the March 2020 ICC service disconnection moratorium proceeding;

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the length and severity of the COVID-19 pandemic, and its impacts on our business continuity plans and our results of operations, financial position, and liquidity, including but not limited to changes in customer demand resulting in changes to sales volumes, customers’ ability to pay for our services, the health and welfare of our workforce and that of our contractors, supplier disruptions, delays in the completion of capital or other construction projects, which could impact our planned capital expenditures and expected planned rate base growth, our attempt to earn our allowed ROEs, the ability to meet customer energy-efficiency program goals and earn performance incentives related to those programs, increased data security risks as a result of the transition to remote working arrangements for a significant portion of our workforce, and our ability to access the capital markets on reasonable terms and when needed;

•	the effect and continuation of Ameren Illinois’ election to participate in performance-based formula ratemaking frameworks for its electric distribution service and its participation in electric energy-efficiency programs, including the direct relationship between Ameren Illinois’ ROE and the 30-year United States Treasury bond yields;

•	the effect on Ameren Missouri of any customer rate caps pursuant to Ameren Missouri’s election to use the PISA, including an extension of use beyond 2023, if requested by Ameren Missouri and approved by the MoPSC;

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

•	the effects of changes in federal, state, or local tax laws, regulations, interpretations, or rates, including as a result of amendments or technical corrections to the TCJA, and challenges to the tax positions taken by the Ameren Companies, if any;

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

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

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

•	our ability to align overall spending, both operating and capital, with frameworks established by our regulators and to recover these costs in a timely manner in our attempt to earn our allowed ROEs;

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the cost and availability of fuel, such as low-sulfur coal, natural gas, and enriched uranium used to produce electricity; the cost and availability of purchased power, zero emission credits, renewable energy credits, and natural gas for distribution; and the level and volatility of future market prices for such commodities and credits, including our ability to recover the costs for such commodities and credits and our customers’ tolerance for any related price increases;

•	disruptions in the delivery of fuel, failure of our fuel suppliers to provide adequate quantities or quality of fuel, or lack of adequate inventories of fuel, including nuclear fuel assemblies from the one NRC-licensed supplier of Ameren Missouri’s Callaway Energy Center’s assemblies;

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

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

•	the ability to obtain sufficient insurance, including insurance for Ameren Missouri’s nuclear and coal-fired energy centers, or, in the absence of insurance, the ability to recover uninsured losses from our customers;

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

•	business and economic conditions, which have been affected by, and will be affected by the length and severity of, the COVID-19 pandemic, including the impact of such conditions on interest rates, collection of our receivable balances, and demand for our products;

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

•	the actions of credit rating agencies and the effects of such actions, including any impacts on our credit ratings that may result from the economic conditions of the COVID-19 pandemic;

•	the inability of our counterparties to meet their obligations with respect to contracts, credit agreements, and financial instruments;

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

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

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

•	the operation of Ameren Missouri’s Callaway Energy Center, including planned and unplanned outages, and decommissioning costs;

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

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

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

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Ameren Missouri’s ability to acquire wind and other renewable energy generation facilities and recover its cost of investment and related return in a timely manner, which is affected by the ability to obtain all necessary project approvals; the ability of developers to meet contractual commitments and timely complete projects, which is dependent upon the availability of necessary materials and equipment, including those that are affected by the disruptions in the global supply chain caused by the COVID-19 pandemic, among other things; the availability of federal production and investment tax credits related to renewable energy and Ameren Missouri’s ability to use such credits; the cost of wind and solar generation technologies; and Ameren Missouri’s ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost for each facility;

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

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

•	the impact of adopting new accounting guidance;

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

•	legal and administrative proceedings; and

•	acts of sabotage, war, terrorism, or other intentionally disruptive acts.

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

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

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

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(a)	The timing of peak credit facility borrowings varies by company. Therefore, the sum of individual company peak amounts may not equal the Ameren consolidated peak credit facility borrowings for the period.

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

(b)	In the first quarter of 2020, Ameren Missouri’s peak interest rate was affected by temporary disruptions in the commercial paper market.

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(a)	For the three months ended March 31, 2020 and 2019, the non-service cost components of net periodic benefit income were partially offset by a deferral of $6 million and $7 million, respectively, due to a regulatory tracking mechanism for the difference between the level of such costs incurred by Ameren Missouri under GAAP and the level of such costs included in rates.

(b)	Includes $8 million pursuant to Ameren Missouri’s March 2020 electric rate order. See Note 2 – Rate and Regulatory Matters for additional information.

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

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

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

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

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(a)	Balance excludes $16 million and $5 million of cash and cash equivalents, receivables, payables, and accrued income, net, for March 31, 2020, and December 31, 2019, respectively.

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

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

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

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(b)	Unobservable inputs were weighted by relative fair value

(c)	Valuations through 2029 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2029 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials.

(d)	Valuations through 2028 use visible forward prices adjusted for nodal-to-hub basis differentials. Valuations beyond 2028 use a trend rate factor and are similarly adjusted for nodal-to-hub basis differentials.

(a)

Ameren and Ameren Missouri have investments in industrial development revenue bonds, classified as held-to-maturity and recorded in “Other Assets,” that are equal to the finance obligations for the Peno Creek and Audrain CT energy centers. As of March 31, 2020, and December 31, 2019, the carrying amount of both the investments in industrial development revenue bonds and the finance obligations approximated fair value.

(b)

Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $73 million, $32 million, and $34 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of March 31, 2020. Included unamortized debt issuance costs, which were excluded from the fair value measurement, of $72 million, $30 million, and $34 million for Ameren, Ameren Missouri, and Ameren Illinois, respectively, as of December 31, 2019.

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

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

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

(a)	Not applicable.

(b)	Amount less than $1 million.

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(a)	Includes amounts for generation and for distribution.

(b)	The purchased power amounts for Ameren and Ameren Illinois exclude agreements for renewable energy credits through 2035 with various renewable energy suppliers due to the contingent nature of the payment amounts, with the exception of expected payments of $15 million through 2024.

(c)	The purchased power amounts for Ameren and Ameren Missouri exclude a 102-megawatt power purchase agreement with a wind farm operator, which expires in 2024, due to the contingent nature of the payment amounts.

(d)

In January 2018, as required by the FEJA, Ameren Illinois entered into agreements to acquire zero emission credits, through 2026. Annual zero emission credit commitment amounts will be published by the IPA each May prior to the start of the subsequent planning year. The amounts above reflect Ameren Illinois’ commitment to acquire approximately $11 million of zero emission credits through May 2020.

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

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

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

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

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

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

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

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

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

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(a)	Ameren Illinois has a rate-adjustment mechanism that allows it 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.

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(a)	Balance included $53 million in “Other current liabilities” on the balance sheet as of both December 31, 2019, and March 31, 2020.

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

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

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(a)	There were no potentially dilutive securities excluded from the earnings per diluted share calculations for the three months ended March 31, 2020 and 2019.

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

(a)	Ameren Illinois Transmission earns revenue from transmission service provided to Ameren Illinois Electric Distribution.

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(a)	The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the three months ended March 31, 2020 and 2019:

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(a)	The following table presents increases/(decreases) in revenues from alternative revenue programs and other revenues not from contracts with customers for the Ameren Illinois segments for the three months ended March 31, 2020 and 2019:

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

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

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

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•	increased other operation and maintenance expenses not subject to riders or regulatory tracking mechanisms, excluding the absence of the Callaway Energy Center’s scheduled refueling and maintenance outage costs, primarily due to changes in the cash surrender value of company-owned life insurance (8 cents per share);

•	the absence in 2020 of MEEIA 2013 and MEEIA 2016 performance incentives at Ameren Missouri recognized in the first quarter of 2019 (6 cents per share);

•	decreased electric retail sales at Ameren Missouri, primarily due to milder winter temperatures experienced in 2020 (estimated at 5 cents per share);

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•	decreased income tax benefits at Ameren (parent) related to stock-based compensation and company-owned life insurance (5 cents per share);

•	decreased Ameren Illinois Electric Distribution earnings under formula ratemaking because of a lower recognized ROE (2 cents per share); and

•	increased charitable donations at Ameren Missouri pursuant to its March 2020 electric rate order (2 cents per share).

•	increased Ameren Transmission and Ameren Illinois Electric Distribution earnings under formula ratemaking because of additional rate base investments (3 cents per share);

•	decreased other operation and maintenance expenses related to the absence of a Callaway Energy Center’s scheduled refueling and maintenance outage, which last occurred in the second quarter of 2019, and the deferral of 2020 outage expenses under the February 2020 MoPSC order (2 cents per share);

•	increased Ameren Illinois Natural Gas earnings from investments in qualifying infrastructure recovered under the QIP rider (1 cent per share); and

•	decreased net financing costs at Ameren Missouri, primarily as a result of the regulatory deferral of interest expense pursuant to the PISA, partially offset by lower levels of the allowance for funds used during construction (1 cent per share).

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(a)	Includes other/intersegment eliminations of $(9) million and $(8) million in the three months ended March 31, 2020 and 2019, respectively.

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(a)	Includes an increase in transmission margins of $4 million at Ameren Illinois for the three months ended March 31, 2020, compared with the year-ago period.

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

(c)	For Ameren Illinois Electric Distribution and Ameren Transmission, base rates include increases or decreases to operating revenues related to the revenue requirement reconciliation adjustment under formula rates.

(d)	Electric and natural gas revenue changes are offset by corresponding changes in “Fuel,” “Purchased power,” and “Natural gas purchased for resale” on the statement of income, resulting in no change to electric and natural gas margins.

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

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Winter temperatures were milder as heating degree days decreased 16% for the three months ended March 31, 2020. The aggregate effect of weather decreased margins an estimated $20 million. The change in margins due to weather is the sum of the effect of weather (estimate) on electric revenues (-$27 million) and the effect of weather (estimate) on fuel and purchased power (+$7 million) in the table above.

•	The absence in 2020 of MEEIA 2013 and MEEIA 2016 performance incentives, which were recognized in the first quarter of 2019, decreased revenues $20 million. See Note 2 – Rate and Regulatory Matters under Part I, Item 1 of this report for information regarding the MEEIA 2013 and MEEIA 2016 performance incentives.

•	Net energy costs increased margins $2 million as a result of lower energy costs (+$24 million), largely offset by a reduction in off-system sales revenue (-$22 million). The decrease in energy costs is the result of lower fuel costs and decreased generation volumes, while the reduction in off-system sales revenues is primarily due to lower sales prices.

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Excluding the estimated effects of weather and the MEEIA 2016 and 2019 customer energy-efficiency programs, electric revenues increased an estimated $1 million for the three months ended March 31, 2020. The increase was primarily due to an increase in the average retail price per kilowatthour due to changes in customer usage patterns (+$2 million). The benefit of the higher average retail price was partially offset by a decrease to sales volumes (-$1 million), which were unfavorably affected the COVID-19 pandemic, but favorably affected by an additional day in 2020 as a result of the leap year. While the MEEIA 2016 and 2019 customer energy-efficiency programs reduced retail sales volumes, the recovery of lost electric margins ensured that electric margins were not affected.

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(a)	Includes other/intersegment eliminations of $(2) million in the three months ended March 31, 2020.

•	The cash surrender value of company-owned life insurance decreased $15 million, because of unfavorable market returns.

•	Labor and benefit costs increased $7 million, primarily because of increased staffing to support the Smart Energy Plan and higher medical costs.

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•	Callaway Energy Center refueling operations and maintenance costs decreased $7 million. Costs were incurred in the prior year period in preparation for the refueling and maintenance outage that began in April 2019. Costs for the current year’s fall refueling and maintenance outage are being deferred pursuant to the March 2020 MoPSC electric rate order.

•	MEEIA customer energy-efficiency program costs decreased $3 million because of lower participation in the MEEIA programs.

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(a)	Includes $2 million and $1 million at Ameren Transmission in the three months ended March 31, 2020 and 2019, respectively, and other/intersegment eliminations of $3 million and $4 million in the three months ended March 31, 2020 and 2019, respectively.

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(a)	Estimate of the annual effective income tax rate adjusted to reflect the tax effect of items discrete to the three months ended March 31, 2020 and 2019.

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•	A $39 million decrease resulting from decreased customer collections, primarily due to a decrease in weather-related sales volumes at Ameren Missouri, partially offset by a net increase attributable to regulatory recovery mechanisms, decreased fuel costs and production volumes at Ameren Missouri, and decreased purchase power costs and volumes and natural gas costs at Ameren Illinois.

•	A $30 million decrease resulting from an increase in coal inventory levels due to delivery disruptions that occurred from flooding in 2019.

•	A $15 million increase in property tax payments at Ameren Missouri due to higher property tax values in 2019, compared with 2018. Property tax payments in a given year are based on the preceding year’s property tax values.

•	A $44 million decrease resulting from decreased customer collections, primarily due to a decrease in weather-related sales volumes, partially offset by decreased fuel costs and production volumes and a net increase attributable to regulatory recovery mechanisms.

•	A $30 million decrease resulting from an increase in coal inventory levels due to delivery disruptions that occurred from flooding in 2019.

•	A $15 million increase in property tax payments due to higher property tax values in 2019, compared with 2018. Property tax payments in a given year are based on the preceding year’s property tax values.

•	A $5 million increase primarily resulting from decreased purchased power costs and volumes and decreased natural gas costs, as well as the change in customer receivable balances, partially offset by a net decrease attributable to regulatory recovery mechanisms.

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(a)	Ameren issued a total of 0.2 million and 0.3 million shares of common stock under its DRPlus and 401(k) plan in the three months ended March 31, 2020 and 2019, respectively.

(b)	Excludes 0.5 million and 0.8 million shares of common stock valued at $38 million and $54 million issued for no cash consideration in connection with stock-based compensation for the three months ended March 31, 2020 and 2019, respectively.

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The COVID-19 pandemic is a rapidly evolving situation. While the COVID-19 pandemic did not have a material impact on our results of operations, financial position, or liquidity for the three months ended March 31, 2020, it may adversely affect our results of operations, financial position, or liquidity in subsequent periods. The effect will depend on the severity and longevity of the COVID-19 pandemic and the resulting impact on business, economic, and capital market conditions. Shelter-in-place orders began taking effect in our service territories in mid-March 2020. These orders generally require individuals to remain at home and preclude or limit the operation of businesses that are deemed nonessential. While Ameren's business operations are deemed essential and are not directly impacted by the shelter-in-place orders, approximately 65% of our workforce transitioned to remote working arrangements in mid-March. We are monitoring the impacts the pandemic is having on our businesses, including but not limited to potential impacts on our liquidity and financing plans; demand for residential, commercial, and industrial electric and natural gas services; more flexible payment plans for customers; bad debt expense; supply chain operations; the availability of our employees and contractors; counterparty credit; capital construction, infrastructure operations and maintenance, and energy efficiency programs; and pension valuations. On March 13, 2020, and March 16, 2020, Ameren Illinois and Ameren Missouri, respectively, suspended customer disconnections for non-payment and began to waive late fees. Regarding bad debt expense, Ameren Illinois' electric distribution and natural gas distribution businesses have bad debt riders, which would provide for recovery of increased bad debt expense. However, Ameren Missouri’s earnings are exposed to potential increases in future bad debt expense, which could result in incremental accounts receivable write-offs in future periods as

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The PISA permits Ameren Missouri to defer and recover 85% of the depreciation expense and a return at the applicable WACC on investments in certain property, plant, and equipment placed in service after September 1, 2018, and not included in base rates. The regulatory asset for accumulated PISA deferrals also earns a return at the applicable WACC, with all approved PISA deferrals added to rate base prospectively and recovered over a period of 20 years following a regulatory rate review. Additionally, under the RESRAM, Ameren Missouri is permitted to recover the 15% of depreciation expense and a return at the applicable WACC for investments in renewable generation plant placed in service and not recovered under the PISA. Accumulated RESRAM deferrals earn carrying costs at short-term interest rates. The PISA and the RESRAM mitigate the effects of regulatory lag between regulatory rate reviews. Those investments not eligible for recovery under the PISA and the remaining 15% of certain property, plant, and equipment placed in service, unless eligible for recovery under the RESRAM, remain subject to regulatory lag. Ameren Missouri recognizes the cost of debt on PISA deferrals in revenue, instead of using the applicable WACC, with the difference recognized in revenues when recovery of such deferrals is reflected in customer rates. As a result of the PISA election, additional provisions of the law apply to Ameren Missouri, including limitations on electric customer rate increases. Both the rate increase limitation and PISA are effective through December 2023, unless Ameren Missouri requests and receives MoPSC approval of an extension through December 2028.

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In February 2020, Ameren Missouri filed an update to its Smart Energy Plan with the MoPSC, which includes a five-year capital investment overview with a detailed one-year plan for 2020. The plan is designed to upgrade Ameren Missouri’s electric infrastructure and includes investments that will upgrade the grid and accommodate more renewable energy. Investments under the plan are expected to total approximately $7.6 billion over the five-year period from 2020 through 2024, with expenditures largely recoverable under the PISA and the RESRAM. The planned investments in 2024 are based on the assumption that Ameren Missouri requests and receives MoPSC approval of an extension of the PISA through December 2028. As a part of its Smart Energy Plan, Ameren Missouri expects to build solar generation facilities, including utility scale facilities and nonresidential customer site facilities. In September 2019, Ameren Missouri filed for certificates of convenience and necessity with the MoPSC to build three solar facilities in its service territory. Each 10-megawatt solar energy generation facility will connect to battery storage in order to improve system reliability. All three facilities are expected to be completed by 2022. Also in 2019, the MoPSC approved Ameren Missouri’s Charge Ahead program, which provides incentives for the development of over 1,000 electric vehicle charging stations along highways and at various locations in communities throughout Ameren Missouri’s service territory. The purpose of the program is to promote the development of electric vehicle charging infrastructure that will enable long-distance electric vehicle travel and encourage electrification of the transportation sector.

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In 2018, the MoPSC issued an order approving Ameren Missouri’s MEEIA 2019 plan. The plan includes a portfolio of customer energy-efficiency programs through December 2021 and low-income customer energy-efficiency programs through December 2024, along with a rate-adjustment mechanism. Ameren Missouri intends to invest $226 million over the life of the plan, including $65 million per year through 2021. The plan includes the continued use of the MEEIA rider, which allows Ameren Missouri to collect from, or refund to, customers any difference in actual MEEIA program costs and related lost electric margins and the amounts collected from customers. In addition, the plan includes a performance incentive that provides Ameren Missouri an opportunity to earn additional revenues by achieving certain customer energy-efficiency goals. If the target goals are achieved for 2019, 2020, and 2021, which could be affected by the COVID-19 pandemic, additional revenues of $7 million, $10 million, and $13 million would be recognized in late 2020, 2021, and 2022, respectively. Incremental additional revenues of $1 million, $3 million, and $3 million may be earned for 2019, 2020, and 2021,

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In March 2020, the MoPSC issued an order in Ameren Missouri’s July 2019 electric service regulatory rate review, approving nonunanimous stipulation and agreements. The order resulted in a decrease of $32 million to Ameren Missouri's annual revenue requirement for electric retail service. The order also provided for the continued use of the FAC and trackers for pension and postretirement benefits, uncertain income tax positions, and certain excess deferred income taxes that the MoPSC previously authorized in earlier electric rate orders. The order reduced the annualized base level of net energy costs pursuant to the FAC by approximately $115 million from the base level established in the MoPSC’s March 2017 electric rate order. The order also changed the annualized regulatory asset and liability amortization amounts and the base level of expenses for regulatory tracking mechanisms. These changes will result in approximately $20 million of increased revenues and approximate decreases in purchased power expenses of $15 million, other operating and maintenance expenses of $60 million, and income tax expenses of $20 million. An estimated $70 million would have otherwise been deferred under the PISA. A stipulation and agreement approved by the MoPSC’s March 2020 order states that the net impact of the revenue and expense changes noted above reflect a 9.4% to 9.8% ROE on an unspecified percent of common equity applicable to rate base. In addition, the order required Ameren Missouri to donate $8 million to low-income assistance programs, which was reflected in results of operations for the three months ended March 31, 2020. The new rates, base level of expenses, and amortizations became effective on April 1, 2020. In April 2020, the MoPSC issued another order in Ameren Missouri’s July 2019 electric service regulatory rate review, reaffirming the existing percentage of net energy cost variances allowed to be recovered or refunded under the FAC.

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Ameren Illinois and ATXI use a forward-looking rate calculation with an annual revenue requirement reconciliation for each company’s electric transmission business. Based on expected rate base growth and the currently allowed 10.38% ROE, the revenue requirements included in 2020 rates for Ameren Illinois’ and ATXI’s electric transmission businesses are $311 million and $190 million, respectively. These revenue requirements represent an increase in Ameren Illinois’ and ATXI’s revenue requirements of $14 million and $13 million, respectively, from the revenue requirements reflected in 2019 rates, primarily due to expected rate base growth. These rates will affect Ameren Illinois’ and ATXI’s cash receipts during 2020, but will not determine their respective electric transmission service operating revenues, which will instead be based on 2020 actual recoverable costs, rate base, and a return on rate base at the applicable WACC as calculated under the FERC formula ratemaking framework.

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In February 2020, MISO, on behalf of Ameren Illinois, filed a request with the FERC to revise Ameren Illinois’ transmission formula rate calculation with respect to calculation inputs for materials and supplies. In May 2020, the FERC issued an order approving the revisions prospectively. In addition, the FERC noted that the FERC staff should review historical rate recovery in connection with an ongoing FERC audit. At this time, Ameren and Ameren Illinois are evaluating this order, but do not expect the impact to be material on their results of operations, financial position, or liquidity.

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The ROE for MISO transmission owners, including Ameren Illinois and ATXI, is the subject of FERC complaint cases filed in November 2013 and February 2015 challenging the allowed base ROE. In November 2019, the FERC issued an order addressing the November 2013 complaint case, which set the allowed base ROE at 9.88% and required refunds, with interest, for the periods November 2013 to February 2015 and from late September 2016 forward. The order also dismissed the February 2015 complaint case. As a result of this order, Ameren and Ameren Illinois expect to pay refunds of approximately $40 million and $23 million, respectively, in 2020. In December 2019, Ameren and the MISO transmission owners, including Ameren Missouri, Ameren Illinois, and ATXI, filed requests for rehearing with the FERC. Additionally, in December 2019, various parties filed requests for rehearing with the FERC, challenging the dismissal of the February 2015 complaint case. The FERC has not ruled on the merits of the rehearing requests and is under no deadline to do so. In March 2019, the FERC issued separate Notices of Inquiry regarding its allowed base ROE policy and its transmission incentives policy. Initial comments were due by June 2019, and reply comments were due by late August 2019. The Notice of Inquiry addressing the FERC’s base ROE policy, among other things, broadened the ability to comment on the new methodology beyond electric utilities that are participants in the complaint cases. The transmission incentives Notice of Inquiry was open for comment on the FERC’s transmission incentive policy, including incentive adders to the base ROE. In March 2020, the FERC issued a Notice of Proposed Rulemaking on its transmission incentives policy, which included an increased incentive in the allowed base ROE for participation in an RTO to 100 basis points from the current 50 basis points and improved parameters for awarding incentives, while limiting the overall incentives to a cap of 250 basis points, among other things. Initial comments are due by July 2020. Ameren is unable to predict the ultimate impact of the Notices of Inquiry, the Notice of Proposed Rulemaking, or the requests for rehearing at this time. A 50 basis point reduction in the FERC-allowed base ROE would reduce Ameren’s and Ameren Illinois’ annual net income by an estimated $10 million and $6 million, respectively, based on each company’s 2020 projected rate base.

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Ameren Illinois’ electric distribution service performance-based formula ratemaking framework allows Ameren Illinois to reconcile electric distribution service rates to its actual revenue requirement on an annual basis. If a given year’s revenue requirement varies from the amount collected from customers, an adjustment is made to electric operating revenues with an offset to a regulatory asset or liability to

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In 2019, the ICC issued an order in Ameren Illinois’ annual update filing that approved a $7 million decrease in Ameren Illinois’ electric distribution service rates beginning in January 2020. Illinois law provides for an annual reconciliation of the electric distribution revenue requirement as is necessary to reflect the actual costs incurred and a return at the applicable WACC on year-end rate base in a given year with the revenue requirement that was reflected in customer rates for that year. Consequently, Ameren Illinois’ 2020 electric distribution service revenues will be based on its 2020 actual recoverable costs, 2020 year-end rate base, and a return at the applicable WACC as calculated under the Illinois performance-based formula ratemaking framework. The 2020 revenue requirement reconciliation will be collected from, or refunded to, customers in 2022. A 50 basis point change in the annual average of the monthly yields of the 30-year United States Treasury bonds would result in an estimated $9 million change in Ameren’s and Ameren Illinois’ annual net income, based on Ameren Illinois’ 2020 projected year-end rate base. Ameren Illinois’ allowed ROE was based on an expected annual average of the monthly yields of the 30-year United States Treasury bonds of 1.6% and 3.1% for the first quarter of 2020 and 2019, respectively.

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In April 2020, Ameren Illinois filed its annual electric distribution service formula rate update to establish the revenue requirement to be used for 2021 rates with the ICC. Pending ICC approval, this update filing will result in a $45 million decrease in Ameren Illinois’ electric distribution service rates, beginning in January 2021. These rates will affect Ameren Illinois' cash receipts during 2021, but will not affect electric distribution service revenues, which will be based on actual recoverable costs, rate base, and return on common equity as calculated under the Illinois performance-based formula ratemaking framework. An ICC decision in this proceeding is expected by December 2020.

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In February 2020, Ameren Illinois filed a request with the ICC seeking approval to increase its annual revenues for natural gas delivery service by $102 million, which includes an estimated $46 million of annual revenues that would otherwise be recovered under the QIP and other riders. The request is based on a 10.5% allowed ROE, a capital structure composed of 54.1% common equity, and a rate base of $2.1 billion. Ameren Illinois used a 2021 future test year in this proceeding. A decision by the ICC in this proceeding is required by January 2021, with new rates expected to be effective in February 2021. Ameren Illinois cannot predict the level of any delivery service rate change the ICC may approve, nor whether any rate change that may eventually be approved will be sufficient to enable Ameren Illinois to earn a reasonable return on investments when the rate changes go into effect.

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In March 2020, the ICC issued an order requiring all Illinois electric distribution, natural gas, water, and sewer utilities to suspend disconnections for customer non-payment and waive late fees, on an interim basis, effective March 18, 2020, and for as long as the public health emergency related to the COVID-19 pandemic remains in effect for the state of Illinois. At this time, the state of Illinois’ public health emergency remains in effect until May 30, 2020. The order also requires utilities to design and implement, upon ICC approval and on a temporary basis, more flexible credit and collection practices. In March 2020, Ameren Illinois filed a response to the ICC order stating their compliance with the suspension of disconnections and late fees for electric distribution and natural gas customers, and proposing more flexible credit and collection practices, including longer deferred payment arrangements for customers that fall behind on bill payments. In April 2020, similar to other utilities in Illinois, Ameren Illinois also requested approval to recover forgone late fees related to natural gas service through its existing bad debt rider and the ability to defer, as a regulatory asset, costs incurred related to the COVID-19 pandemic. Recovery of electric distribution forgone late fees and costs incurred related to the COVID-19 pandemic are included in Ameren Illinois’ electric distribution formula rates. In April 2020, the ICC staff recommended extending the suspension of disconnections and late fees for 60 days beyond when the state of Illinois’ public health emergency has ended. The ICC is under no deadline to issue an order in this proceeding.

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Ameren Illinois earns a return at the applicable WACC on its electric energy-efficiency program investments. Ameren Illinois’ electric energy-efficiency investments are deferred as a regulatory asset and earn a return at the applicable WACC, with the ROE based on the annual average of the monthly yields of the 30-year United States Treasury bonds plus 580 basis points. The allowed ROE on electric energy-efficiency investments can be increased or decreased by up to 200 basis points, depending on the achievement of annual energy savings goals, which may be affected by the COVID-19 pandemic. Pursuant to the FEJA, Ameren Illinois plans to invest up to approximately $100 million per year in electric energy-efficiency programs through 2024, and will earn a return on those investments. While the ICC has approved a plan consistent with this spending level through 2021, the ICC has the ability to reduce the amount of electric energy-efficiency savings goals in future plan program years if there are insufficient cost-effective programs available, which could reduce the investments in electric energy-efficiency programs. The electric energy-efficiency program investments and the return on those investments are collected from customers through a rider and are not included in the electric distribution service performance-based formula ratemaking framework.

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In February 2020, the MoPSC issued an order approving a stipulation and agreement allowing Ameren Missouri to defer and amortize maintenance expenses related to scheduled refueling and maintenance outages at its Callaway Energy Center. Beginning with the fall 2020 refueling and maintenance outage, Ameren Missouri will defer the maintenance expenses incurred related to a refueling and maintenance outage as a regulatory asset and amortize those expenses after completion of the outage. Maintenance expenses will be amortized over the period between refueling and maintenance outages, which is approximately 18 months. Ameren Missouri expects to incur approximately $40 million in maintenance expenses related to the fall 2020 outage. During a scheduled outage, depending on the availability of its other generation sources and the market prices for power, Ameren Missouri’s purchased power costs may increase and the amount of excess power available for sale may decrease versus non-outage years. Changes in purchased power costs and excess power available for sale are included in the FAC, which results in limited impacts to earnings. Prior to 2020, maintenance expenses for refueling and maintenance outages were expensed as incurred.

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Ameren Missouri and Ameren Illinois continue to make infrastructure investments and expect to seek increases to electric and natural gas rates to recover the cost of investments and earn an adequate return. Ameren Missouri and Ameren Illinois will also seek new, or to maintain existing, legislative solutions to address regulatory lag and to support investment in their utility infrastructure for the benefit of their customers. Ameren Missouri and Ameren Illinois continue to face cost recovery pressures, including limited economic growth in their service territories, economic impacts of COVID-19, customer conservation efforts, the impacts of additional customer energy-efficiency programs, and increased customer use of increasingly cost-effective technological advances, including private generation and energy storage. However, over the long-term, we expect the decreased demand to be partially offset by increased demand resulting from increased electrification of the economy for efficiencies and as a means to address economywide CO2 emission concerns. Increased investments, including expected future investments for environmental compliance, system reliability improvements, and potential new generation sources, result in rate base and revenue growth but also higher depreciation and financing costs.

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The COVID-19 pandemic could adversely affect our liquidity and capital resources, including but not limited to potential impacts on collections from our tariff-based revenues, capital expenditures, our ability to access the capital markets on reasonable terms and when needed, Ameren Missouri’s expected 2020 wind generation acquisitions, and the timing of tax payments and the utilization of tax credits. Our customers’ ability to pay for our services may be adversely affected by the COVID-19 pandemic. A reduction in collections from our tariff-based revenues could reduce our cash from operations and cause an adverse impact to our liquidity. We expect to make significant capital expenditures to improve our electric and natural gas utility infrastructure, however, disruptions to the capital markets and the ability of our suppliers and contractors to perform as required under their contracts could impact the execution of our capital investment strategy. For further discussion on the impacts to our ability to access the capital markets, Ameren Missouri’s expected 2020 wind generation acquisitions, and the timing of tax payments and the utilization of tax credits, see below.

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Ameren Missouri’s 2017 IRP targets cleaner and more diverse sources of energy generation, including solar, wind, natural gas, hydro, and nuclear power. It also includes expanding renewable sources by adding 700 megawatts of wind generation by the end of 2020 in Missouri and adding 100 megawatts of solar generation by 2027. These new renewable energy sources would support Ameren Missouri’s compliance with the state of Missouri’s requirement of achieving 15% of native load sales from renewable energy sources by 2021, subject to customer rate increase limitations. Based on current and projected market prices for energy and for wind and solar generation technologies, among other factors, Ameren Missouri expects its ownership of these renewable resources would represent the lowest-cost option for customers. The plan also provides for the expected implementation of continued customer energy-efficiency programs. Ameren Missouri’s plan for the addition of renewable resources could be affected by, among other factors: Ameren Missouri’s ability to obtain a certificate of convenience and necessity from the MoPSC, and any other required project approvals; the ability of developers to meet contractual commitments and timely complete projects, which is dependent upon the availability of necessary materials and equipment, including those that are affected by the disruptions in the global supply chain caused by the COVID-19 pandemic, among other things; the availability of federal production and investment tax credits related to renewable energy and Ameren Missouri’s ability to use such credits; the cost of wind and solar generation technologies; energy prices; and Ameren Missouri’s ability to obtain timely interconnection agreements with the MISO or other RTOs at an acceptable cost. Ameren Missouri expects to file its next integrated resource plan in September 2020. Ameren Missouri will seek stakeholder feedback and assess different scenarios to meet future energy needs, which will be used to create an updated plan for its current generation portfolio and ongoing transition to cleaner sources of energy.

•	In connection with the 2017 IRP filing, Ameren Missouri established a goal of reducing CO2 emissions 80% by 2050 from a 2005 base level. Ameren Missouri is also targeting a 35% CO2 emission reduction by 2030 and a 50% reduction by 2040 from the 2005 level. In order to meet these goals, among other things, Ameren Missouri expects to retire its coal-fired generation at the end of each energy

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Consistent with its 2017 IRP filing, in 2019, Ameren Missouri entered into a build-transfer agreement to acquire, after construction, an up-to 300-megawatt wind generation facility. In 2018, Ameren Missouri entered into a build-transfer agreement to acquire, after construction, an up-to 400-megawatt wind generation facility. These two agreements are subject to customary contract terms and conditions. The two build-transfer acquisitions collectively represent $1.2 billion of capital expenditures and would support Ameren Missouri’s compliance with the Missouri renewable energy standard. Both acquisitions have received all regulatory approvals, and both projects have received all applicable zoning approvals, have entered into RTO interconnection agreements, and have begun construction activities. In 2020, the developers of the wind generation facilities received notices from the wind turbine supplier, and the developer of the up-to 300-megawatt project received a notice from the construction contractor, of changes in supply and/or construction activities resulting from the COVID-19 pandemic. There have been changes to the schedules for both projects, particularly with regard to wind turbine deliveries. Ameren Missouri and the developers continue to monitor the impact to each project schedule. To date, neither developer has reported to Ameren Missouri that the projects will not be completed in 2020. Ameren Missouri expects the up-to 400-megawatt project to be placed in-service by the end of 2020. However, at this time, due to manufacturing, shipping, and other supply chain issues, and based on Ameren Missouri’s discussions with the developer, Ameren Missouri expects that a portion of the up-to 300-megawatt project, representing approximately $100 million of investment, could be placed in-service in the first quarter of 2021. See discussion below related to production tax credits.

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Through 2024, we expect to make significant capital expenditures to improve our electric and natural gas utility infrastructure, with a major portion directed to our transmission and distribution systems. We estimate that we will invest up to $16.6 billion (Ameren Missouri – up to $8.4 billion; Ameren Illinois – up to $8.0 billion; ATXI – up to $0.2 billion) of capital expenditures during the period from 2020 through 2024. Ameren’s and Ameren Missouri’s estimates exclude any capital expenditures related to pollution control equipment that may be required as a result of the NSR and Clean Air Act litigation discussed in Note 9 – Commitments and Contingencies under Part I, Item 1, of this report.

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Environmental regulations, including those related to CO2 emissions, or other actions taken by the EPA, could result in significant increases in capital expenditures and operating costs. Certain of these regulations are being challenged through litigation, or reviewed or recommended for repeal by the EPA, or new replacement or alternative regulations are being contemplated, proposed, or adopted by the EPA and state regulators. The ultimate implementation of any of these regulations, as well as the timing of any such implementation, is uncertain. However, the individual or combined effects of existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of some of Ameren Missouri’s coal-fired energy centers. Ameren Missouri’s capital expenditures are subject to MoPSC prudence reviews, which could result in cost disallowances as well as regulatory lag. The cost of Ameren Illinois’ purchased power and natural gas purchased for resale could increase. However, Ameren Illinois expects that these costs would be recovered from customers with no material adverse effect on its results of operations, financial position, or liquidity. Ameren’s and Ameren Missouri’s earnings could benefit from increased investment to comply with environmental regulations if those investments are reflected and recovered on a timely basis in customer rates.

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The Ameren Companies have multiyear credit agreements that cumulatively provide $2.3 billion of credit through December 2024, subject to a 364-day repayment term for Ameren Missouri and Ameren Illinois, with the option to seek incremental commitments to increase the cumulative credit provided to $2.7 billion. See Note 3 – Short-term Debt and Liquidity under Part I, Item 1, of this report for additional information regarding the Credit Agreements. In November 2020, Ameren (parent)’s $350 million of senior unsecured notes mature, and are expected to be repaid using a portion of the proceeds from Ameren (parent)’s April 2020 issuance of $800 million of senior unsecured notes. The Ameren Companies have no additional maturities of long-term debt until 2022. With the recently completed Ameren Missouri and Ameren (parent) debt issuances and availability under the credit agreements, as well as anticipated proceeds from the settlement of the equity forward discussed below, Ameren, Ameren Missouri, and Ameren Illinois believe that their liquidity is adequate given their expected operating cash flows, capital expenditures, including the expected 2020 wind generation acquisitions, and related financing plans. The Ameren Companies will continue to monitor the effect of the COVID-19 pandemic on their liquidity, including as a result of decreased sales and expected increased customer nonpayment. To date, the Ameren Companies have been able to access the capital markets on reasonable terms when needed. However, there can be no assurance that significant changes in economic conditions, disruptions in the capital and credit markets, or other unforeseen events will not materially affect their ability to execute their expected operating, capital, or financing plans.

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Ameren expects its cash used for currently planned capital expenditures and dividends to exceed cash provided by operating activities over the next several years. As part of its plan to fund these cash flow requirements, Ameren is using newly issued shares of common stock, rather than market-purchased shares, to satisfy requirements under the DRPlus and employee benefit plans and expects to continue to do so through at least 2024. Ameren expects these issuances to provide equity of about $100 million annually. Ameren also plans to issue incremental common equity to fund a portion of Ameren Missouri’s wind generation investments through the physical settlement of the forward sale agreement discussed below. Additionally, Ameren plans to issue incremental equity of about $150 million

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In August 2019, Ameren entered into a forward sale agreement with a counterparty relating to 7.5 million shares of common stock. The forward sale agreement can be settled at Ameren’s discretion on or prior to March 31, 2021. On a settlement date or dates, if Ameren elects to physically settle the forward sale agreement, Ameren will issue shares of common stock to the counterparty at the then-applicable forward sale price. The forward sale agreement will be physically settled unless Ameren elects to settle in cash or to net share settle. If physically settled, Ameren expects to receive between $540 million and $550 million upon settlement. See Note 5 – Long-Term Debt and Equity Financings under Part II, Item 8, of the Form 10-K for additional information.

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As of March 31, 2020, Ameren had $98 million in tax benefits related to federal and state income tax credit carryforwards and $11 million in outstanding income tax refunds and overpayments. Future expected income tax payments and refunds are based on planned capital expenditures and any related income tax credits and, in the case of Ameren Missouri and Ameren Illinois, are consistent with the tax allocation agreement between Ameren (parent) and its subsidiaries. Ameren expects to make income tax payments between $5 million and $75 million in each year from 2020 to 2024, totaling $150 million to $200 million for the five-year period. Ameren Missouri expects to make income tax payments to Ameren (parent) between $35 million and $45 million in 2020. Additionally, Ameren Missouri expects to receive refunds from Ameren (parent) in each year from 2021 to 2024, totaling $60 million to $100 million for the four-year period, primarily due to the expected utilization of federal production tax credits to be generated from its 2020 wind generation acquisitions. Ameren Illinois expects to make income tax payments to Ameren (parent) between $20 million and $30 million in 2020 and between $50 million and $90 million in each year from 2021 to 2024, totaling $260 million to $310 million for the five-year period.

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Ameren Missouri expects its 2020 wind generation acquisitions to generate federal production tax credits between $65 million and $70 million in each year from 2021 to 2030. Ameren expects to utilize approximately $140 million of these federal production tax credits from 2021 to 2024. Delays in the timely completion of the wind generation facilities may affect Ameren’s ability to realize some or all of the anticipated federal production tax credits. Unless relevant regulations are modified by the IRS or applicable legislation is enacted by Congress to include an extension of the December 31, 2020 in-service date criteria, if any portion of these facilities is completed after 2020, Ameren Missouri would need to satisfy additional IRS requirements in order to qualify for all of the anticipated federal production tax credits for such portion. The build-transfer agreements include provisions for the event in which any portion of either project is completed after 2020. In such an event, according to the terms of the agreements, Ameren Missouri would pay a reduced contract price on the portion of the project completed after 2020, to account for risks associated with qualifying for production tax credits, subject to an obligation to later pay such price differential should Ameren Missouri be entitled to receive production tax credits.

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The Coronavirus Aid, Relief, and Economic Security Act is a federal law enacted in March 2020. Provisions in the act include temporary changes to the utilization of net operating losses, temporary suspension of the payment of the employer portion of Social Security taxes, and additional funding for customer energy assistance, among other things. Ameren has implemented certain provisions of the act, and is currently evaluating other provisions of the act. As of March 31, 2020, there was no material impact to Ameren’s, Ameren Missouri’s, and Ameren Illinois’ financial statements.

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In 2018, legislation modifying Missouri tax law was enacted to decrease the state’s corporate income tax rate from 6.25% to 4%, effective January 1, 2020. The effect of this tax decrease is reflected in Ameren Missouri’s electric service rates that became effective on April 1, 2020. Ameren (parent) and nonregistrant subsidiaries do not expect this income tax decrease to have a material impact on net income.

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(a)	Evaluation of Disclosure Controls and Procedures

(b)	Changes in Internal Controls over Financial Reporting

•	Ameren Illinois’ annual electric distribution service formula rate update filed with the ICC in April 2020;

•	Ameren Illinois’ natural gas delivery service regulatory rate review filed with the ICC in February 2020;

•	Ameren Illinois’ QIP reconciliation hearing with the ICC requested in March 2019;

•	the March 2020 ICC service disconnection moratorium proceeding;

•	Ameren and the MISO transmission owners’ request for a rehearing of the November 2019 FERC order related to the November 2013 complaint case;

•	the March 2019 FERC separate Notices of Inquiry regarding its allowed base ROE policy and its transmission incentives policy;

•	the March 2020 FERC Notice of Proposed Rulemaking on its transmission incentives policy;

•	litigation against Ameren Missouri with respect to NSR and the Clean Air Act; and

•	remediation matters associated with former MGP sites of Ameren Illinois.

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